CN111562199B - Method and system for determining energy storage and replacement performance of compact oil - Google Patents
Method and system for determining energy storage and replacement performance of compact oil Download PDFInfo
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Abstract
The invention discloses a method and a system for determining compact oil energy storage displacement performance, and belongs to the technical field of unconventional oil and gas exploitation. The method comprises the following steps: carrying out a wetting property test on a first core sample in the plurality of core samples to obtain hydrophilic property data of the core of the tight oil reservoir to be tested; performing liquid absorption performance test on a second core sample in the plurality of core samples to obtain the seepage data and the diffusion data of the core of the tight oil reservoir to be tested; carrying out imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested; detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids; and determining the influence data of different types of fracturing fluids on the rock core of the tight oil reservoir to be tested based on the T2 spectrum distribution result. The invention realizes better analysis and test on the compact oil reservoir.
Description
Technical Field
The invention relates to the technical field of unconventional oil and gas exploitation, in particular to a method and a system for determining the energy storage and replacement performance of compact oil.
Background
Along with the continuous rising of oil gas demand and the continuous falling of conventional oil gas output in production and life, unconventional oil gas with larger resource potential gradually becomes the mainstream of development.
For tight reservoir development, the processes and methods used in current development processes have been increasingly optimized, for example, a great deal of work has been done on fracture reformation. However, on one hand, the tight oil reservoir has low hole permeability and is greatly different from the drainage and flooding mechanism of the conventional oil reservoir, and on the other hand, the existing fracturing fluid flowback mechanism after fracturing of the tight oil reservoir is still not sufficiently recognized and analyzed, so that the analysis of the after-fracturing modification effect is not clear, and the next construction design is severely restricted.
Based on the above description, there is a need for a method for determining compact oil energy storage displacement performance to realize a better analysis test of a compact oil reservoir from microscopic pores.
Disclosure of Invention
The embodiment of the invention provides a method and a system for determining energy storage and replacement performance of dense oil. The technical scheme is as follows:
in one aspect, a method of determining tight oil energy storage displacement performance is provided, the method comprising:
performing a wettability test on a first core sample in a plurality of core samples to obtain hydrophilic performance data of a core of a tight oil reservoir to be tested, wherein the plurality of core samples are cores derived from at least one oil well of the tight oil reservoir to be tested;
performing liquid absorption performance test on a second core sample in the plurality of core samples to obtain the imbibition data and the diffusion data of the core of the tight oil reservoir to be tested;
carrying out an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested;
detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids;
and determining influence data of the different types of fracturing fluids on the core of the tight oil reservoir to be tested based on the T2 spectrum distribution result.
In a possible implementation manner, the performing a wettability test on a first core sample of the plurality of core samples to obtain hydrophilic performance data of the core of the tight oil reservoir to be tested includes:
performing wetting angle test on the first core sample to obtain a water-gas wetting angle and oil-gas wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested on the basis of the water-gas wetting angle and the oil-gas wetting angle change, wherein crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or the like, or, alternatively,
carrying out wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the compact oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; and repeatedly executing the wetting angle test for a preset number of times, and solving an average value of the obtained hydrophilic performance data.
In a possible implementation manner, the performing a imbibition performance test on a second core sample of the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested includes:
drying the second core sample for a first preset time at a preset temperature;
obtaining the mass of the cooled second core sample;
immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-absorbent fine wire;
obtaining the mass of the second core sample in different time;
and acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-absorption section and a diffusion self-absorption section.
In a possible implementation manner, the performing an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on oil displacement performance of the tight oil reservoir to be tested includes:
performing oil washing treatment on the third core sample;
soaking the third core sample subjected to oil washing treatment in kerosene;
performing pressurization saturation treatment on the third core sample soaked in the kerosene based on a preset pressure and a second preset time;
based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
and acquiring oil displacement data matched with the different types of fracturing fluids, and acquiring influence data of the different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data.
In a possible implementation manner, the detecting a fourth core sample of the multiple core samples based on nuclear magnetic resonance to obtain a T2 spectrum distribution result of the fourth core sample in different types of fracturing fluids includes:
performing oil washing treatment on the fourth core sample;
soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested;
aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time;
based on a fifth preset time, putting the taken fourth core sample into a plurality of different types of fracturing fluids for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
In another aspect, a system for determining a tight oil energy storage displacement performance is provided, the system comprising: a first device, a second device, a third device, and a fourth device;
the first device is used for carrying out wettability test on a first core sample in a plurality of core samples to obtain hydrophilic performance data of a core of a tight oil reservoir to be tested, wherein the plurality of core samples are cores derived from at least one oil well of the tight oil reservoir to be tested;
the second device is used for carrying out imbibition performance test on a second core sample in the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested;
the third device is used for carrying out an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested;
the fourth device is used for detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids, and determining influence data of the different types of fracturing fluids on the core of the tight oil reservoir to be tested based on the T2 spectrum distribution results.
In a possible implementation manner, the first device is further configured to perform a wetting angle test on the first core sample to obtain a water-gas wetting angle and an oil-gas wetting angle change, and obtain hydrophilic performance data of the core of the tight oil reservoir to be tested based on the water-gas wetting angle and the oil-gas wetting angle change, where crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or performing wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; and repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data.
In a possible implementation manner, the second device is further configured to dry the second core sample at a preset temperature for a first preset time; obtaining the mass of the cooled second core sample; immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-absorbent fine wire; obtaining the mass of the second core sample in different time; and acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-absorption section and a diffusion self-absorption section.
In a possible implementation manner, the third device is further configured to perform oil washing processing on the third core sample; soaking the third core sample subjected to oil washing treatment in kerosene; performing pressurization saturation treatment on the third core sample soaked in the kerosene based on a preset pressure and a second preset time; based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; and acquiring oil displacement data matched with the fracturing fluids of different types, and acquiring influence data of the fracturing fluids of different types on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data.
In a possible implementation manner, the fourth device is further configured to perform oil washing processing on the fourth core sample; soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested; aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time; based on a fifth preset time, placing the taken out fourth core sample in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
The technical scheme provided by the embodiment of the invention has the following beneficial effects:
the embodiment of the invention realizes the wetting performance test of the core sample of the compact oil reservoir to be tested to judge the hydrophilicity of the core sample, obtains the imbibition and diffusion capacity of the core sample by utilizing the imbibition performance test, analyzes the influence of different types of fracturing fluids on the oil displacement potential of the compact oil reservoir by utilizing the imbibition oil displacement test, and detects the change of the different types of fracturing fluids on the core sample by utilizing nuclear magnetic resonance.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow chart of a first method for determining the energy storage displacement performance of a dense oil according to an embodiment of the present invention;
FIG. 2 is a flow chart for determining compact oil energy storage displacement performance according to a second embodiment of the present disclosure;
fig. 3 is a schematic structural diagram of an apparatus for determining dense oil energy storage displacement performance according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
FIG. 1 is a flow chart of a method for determining the energy storage displacement performance of dense oil according to an embodiment of the invention.
Referring to fig. 1, the method includes:
101. and carrying out a wetting property test on a first core sample in the plurality of core samples to obtain hydrophilic property data of the core of the tight oil reservoir to be tested, wherein the plurality of core samples are cores derived from at least one oil well of the tight oil reservoir to be tested.
102. And carrying out liquid absorption performance test on a second core sample in the plurality of core samples to obtain the seepage data and the diffusion data of the core of the tight oil reservoir to be tested.
103. And carrying out imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested.
104. And detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids.
105. And determining the influence data of different types of fracturing fluids on the rock core of the tight oil reservoir to be tested based on the T2 spectrum distribution result.
The method provided by the embodiment of the invention realizes the wetting performance test of the core sample of the tight oil reservoir to be tested to judge the hydrophilicity of the core sample, obtains the imbibition and diffusion capacity of the core sample by using the imbibition performance test, analyzes the influence of different types of fracturing fluids on the oil displacement potential of the tight oil reservoir by using the imbibition displacement test, detects the change of different types of fracturing fluids on the core sample by using nuclear magnetic resonance, determines the interaction between the tight oil reservoir and the fracturing fluids through the tests, determines the energy storage and displacement performance of the tight oil, can accurately analyze the oil displacement potential of the tight oil reservoir and the influence of different types of fracturing fluids on the imbibition displacement potential, and realizes the better analysis and test of the tight oil reservoir from microscopic pores.
In a possible implementation manner, the performing a wettability test on a first core sample of the plurality of core samples to obtain hydrophilic performance data of the core of the tight oil reservoir to be tested includes:
performing wetting angle test on the first core sample to obtain a water-gas wetting angle and oil-gas wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested on the basis of the water-gas wetting angle and the oil-gas wetting angle change, wherein crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or the like, or, alternatively,
carrying out wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the compact oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; and repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data.
In a possible implementation manner, the performing a imbibition performance test on a second core sample of the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested includes:
drying the second core sample for a first preset time at a preset temperature;
obtaining the mass of the cooled second core sample;
immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-absorbent fine wire;
obtaining the mass of the second core sample in different time;
and acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-absorption section and a diffusion self-absorption section.
In a possible implementation manner, the performing an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested includes:
performing oil washing treatment on the third core sample;
soaking the third core sample subjected to oil washing treatment in kerosene;
performing pressurization saturation treatment on the third core sample soaked in the kerosene based on preset pressure and second preset time;
based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
and acquiring oil displacement data matched with the different types of fracturing fluids, and acquiring influence data of the different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data.
In a possible implementation manner, the detecting a fourth core sample of the multiple core samples based on nuclear magnetic resonance to obtain a T2 spectrum distribution result of the fourth core sample in different types of fracturing fluids includes:
performing oil washing treatment on the fourth core sample;
soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested;
aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time;
based on a fifth preset time, putting the taken fourth core sample into a plurality of different types of fracturing fluids for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
All the above optional technical solutions may be combined arbitrarily to form the optional embodiments of the present disclosure, and are not described herein again.
FIG. 2 is a flow chart of a method for determining the energy storage displacement performance of the compact oil according to the embodiment of the invention.
Referring to fig. 2, the method includes:
201. a plurality of core samples of at least one well of a tight oil reservoir to be tested are obtained.
In order to clarify the interaction between the compact oil reservoir and the fracturing fluid, the embodiment of the invention mainly tests the compact oil reservoir to be tested in the following four aspects: the method comprises the steps of judging the hydrophilicity of a rock core by utilizing a rock wettability test, obtaining the imbibition and diffusion capacity of the rock core by utilizing a spontaneous imbibition test, analyzing the influence of different types of fracturing fluids on the oil displacement potential of a compact oil reservoir by utilizing an imbibition oil displacement test, and detecting the change of the different types of fracturing fluids on the rock core by utilizing nuclear magnetic resonance.
It should be noted that, in the tests of the several aspects, the core of the tight oil reservoir to be tested is used, so that the embodiment of the present invention obtains a plurality of core samples of at least one oil well of the tight oil reservoir to be tested.
In addition, the first, second, third and fourth of the first, second, third and fourth core samples mentioned hereinafter are only for the purpose of distinguishing core samples subjected to different tests and do not constitute any other limitation of the core samples.
202. And carrying out a wetting property test on a first core sample in the plurality of core samples to obtain hydrophilic property data of the core of the compact oil reservoir to be tested.
In the embodiment of the invention, the hydrophilicity of the core sample, namely the hydrophilicity of the core of the tight oil reservoir to be tested, is obtained by carrying out a wetting property test, namely a wetting angle test on the core sample. The wettability of the rock influences the imbibition oil displacement efficiency of the compact oil reservoir, and the hydrophilic rock can effectively enhance the imbibition oil displacement efficiency. Therefore, the embodiment of the invention realizes basic qualification of the dialysis oil displacement capability of the compact oil reservoir by judging the wettability of the rock.
In the embodiment of the invention, a Kino wetting angle/interfacial tension meter is used for testing the wetting angle of the rock core sample. Illustratively, the wetting angle test includes both a drip method and a pendant drip method.
The liquid drop method is that crude oil and distilled water are dropped on the surface of a core sample, and the crude oil and the distilled water exist on the surface of the core sample in an expression mode; and acquiring the changes of the water-gas wetting angle and the oil-gas wetting angle. In detail, a wetting angle test is carried out on the first core sample to obtain a water-gas wetting angle and oil-gas wetting angle changes, and hydrophilic performance data of the core of the compact oil reservoir to be tested is obtained based on the water-gas wetting angle and the oil-gas wetting angle changes. Repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or the like, or, alternatively,
the hanging drop method is to soak a core sample in water, then drop oil on the lower surface of the core sample, and change the expression mode into the hanging drop method, wherein the core sample is soaked in water and crude oil exists on the lower surface of the core sample, so that the change of the wetting angle of water and oil is obtained. In detail, a wetting angle test is carried out on a first core sample to obtain water-oil wetting angle change, and hydrophilic performance data of the core of the tight oil reservoir to be tested is obtained based on the water-oil wetting angle change; the wetting angle test is repeatedly performed a preset number of times, and the average value of the obtained hydrophilic performance data is obtained.
The value of the preset number may be 2, which is not specifically limited in this embodiment of the present invention. That is, in order to ensure the accuracy of the test, each core sample is tested for a plurality of times, and if the value of the preset number is 2, the average value of the 2 tests is obtained.
203. And carrying out liquid absorption performance test on a second core sample in the plurality of core samples to obtain the seepage data and the diffusion data of the core of the tight oil reservoir to be tested.
In the embodiment of the invention, spontaneous imbibition test is carried out on the core sample of the tight oil reservoir to research the imbibition and diffusion capacity of the core sample. The method is characterized in that the method comprises the steps of compact oil reservoir energy supplement caused by imbibition and phase permeation conversion caused by ion exchange, imbibition characteristic curves including imbibition capacity, imbibition rate, diffusion rate and other imbibition parameters can be obtained through research, and the method is specifically used for analyzing and evaluating fracturing fluid imbibition capacity and law of compact oil reservoirs. The spontaneous imbibition test can be performed on the cores of two oil wells of the compact oil reservoir, and the embodiment of the invention is not particularly limited to this. Additionally, the initial size and initial mass of the core sample were recorded as the test was performed.
In a possible implementation manner, a liquid absorption performance test is performed on a second core sample in a plurality of core samples to obtain imbibition data and diffusion data of a core of a tight oil reservoir to be tested, and the method comprises the following steps:
(1) And drying the second core sample for a first preset time at a preset temperature.
The preset temperature may be 105 ℃, and the first preset time period may be 24 hours, which is not particularly limited in the embodiment of the present invention. For example, the second core sample may be placed in an oven at 105 ℃ and dried for 24 hours.
(2) And obtaining the mass of the cooled second core sample.
According to the step, the second core sample is taken out, and the mass of the cooled second core sample is obtained by using an analytical balance after the second core sample is cooled. Illustratively, the measurement accuracy of the analytical balance may be 0.0001g, which is not particularly limited by the embodiments of the present invention.
(3) And immersing the cooled second core sample in fracturing fluid, namely adjusting the height of the liquid level, so that the second core sample is completely immersed in the liquid.
The second core sample is suspended in the fracturing fluid through an inelastic and non-water-absorbing thin wire, wherein the diameter of the thin wire may be 0.128mm, which is not specifically limited in this embodiment of the present invention.
Note that, in order to avoid an error due to a drop in the liquid level, the above test was performed in a constant temperature and humidity environment.
(4) And obtaining the quality of the second core sample in different time.
For this step, a mass of the second core sample over time is obtained, wherein the recorded data does not include the initial mass of the second core sample.
(5) And acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-absorption section and a diffusion self-absorption section.
Aiming at the step, the embodiment of the invention obtains the secondary root drawing of the imbibition amount and the time based on the test result obtained in the step (4), and obtains the imbibition characteristic curve comprising the capillary self-priming section and the diffusion self-priming section.
It should be noted that, because the micro-nano pores exist in the compact oil reservoir, a strong diffusion effect exists in the later stage, that is, the fluid sucked into the large pore channel diffuses into the matrix nano pores under the action of capillary force and the like.
Based on the above description, the influence factors of the spontaneous imbibition of the fracturing fluid can be summarized as the following aspects:
(1) The porosity, the permeability and the pore distribution characteristics are positively correlated with the imbibition amount, and the existence of micro-nano pores can generate larger capillary force when the rock core is contacted with water, so that the water is imbibed into the rock core.
(2) And by combining with the wettability test of the rock core sample, the hydrophilicity of the rock is positively correlated with the imbibition capacity of the rock, the better the hydrophilicity is, the larger the capillary force is, and the larger the imbibition rate is.
(3) Clay mineral content has important influence to imbibition ability, because clay mineral exists and to make the rock core produce osmotic pressure when contacting with water, under the effect of osmotic pressure during the water can slowly diffuse into the rock core, wherein, clay mineral's content is higher, the diffuser section water absorption capacity is big more.
In the embodiment of the present invention, the drainage effect of the tight oil reservoir to be tested is generally based on the imbibition displacement test and the imbibition drainage nuclear magnetic resonance test, and please refer to steps 204 to 205 in detail below.
204. And performing an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested.
The method is used for analyzing the influence of different types of fracturing fluids on the oil displacement potential of the compact oil reservoir. In another expression, the method is used for determining the influence of water with different mineralization degrees and fracturing fluid with different properties on the drainage effect of the crude oil. The method can be briefly described as follows: the method comprises the steps of firstly drying a rock core sample, then vacuumizing, enabling the rock core sample to be in an oil saturation state under the condition of applying pressure, finally placing the rock core sample in the oil saturation state in oil displacement bottles filled with different types of fracturing fluids, and obtaining the change condition of the volume of the displaced oil along with time.
The fracturing fluid includes, but is not limited to, distilled water, a high and low salinity solution, a nanomaterial displacement fluid, and the like, and this is not particularly limited in this embodiment of the present invention.
In a possible implementation manner, a third core sample in the plurality of core samples is subjected to an imbibition oil displacement test to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested, and the method comprises the following steps:
(1) And carrying out oil washing treatment on the third core sample.
The number of the third core samples may be 5, for example, five core blocks of a tight oil reservoir are selected, the length of the core is 25mm, the diameter of the core is 25mm, and then oil washing treatment is performed.
(2) And soaking the third core sample subjected to the oil washing treatment in kerosene, and performing pressurization saturation treatment on the third core sample soaked in the kerosene based on the preset pressure and the second preset time.
The preset pressure may be 15Mpa, and the second preset time period may be one week, which is not particularly limited in the embodiment of the present invention. Illustratively, the third core sample is soaked in kerosene (e.g., density 0.82 g/cm) 3 Viscosity 2.2Mpa · s), then pressure saturation at 15Mpa, and after one week of saturation, a third core sample was taken.
(3) And placing the third core sample after being taken out in fracturing fluids of various different types for imbibition displacement based on a third preset time length, wherein one core sample is placed in one type of fracturing fluid.
The third preset time period may be one week, which is not specifically limited in the embodiment of the present invention. For example, taking the number of the core samples as 5, the core samples taken out can be respectively put into five displacement bottles filled with distilled water, 2000ppm nacl, 10000ppm nacl, 50000ppm nacl and 2000ppm cacl2, imbibition displacement is performed for one week, oil displacement data matched with different types of fracturing fluids is obtained, and further, influence data of the different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested is obtained based on the oil displacement data.
The first point to be noted is that the present example utilizes different types of fracturing fluids to displace cores that are in kerosene saturation. In the rock cores with similar physical properties, the rock cores in a kerosene saturation state are displaced by distilled water, 2000ppmNaCl, 10000ppmNaCl, 50000ppmNaCl and 2000ppmCaCl2, and the conclusion that the displacement percentage is reduced along with the increase of the mineralization degree of the fracturing fluid can be drawn, for example, the displacement efficiency of a low-concentration divalent ion solution is far less than that of a low-concentration NaCl solution. This demonstrates that low salinity fracturing fluids can increase flooding efficiency.
The second point to be noted is that the osmotic pressure involved in enhanced recovery of low salinity water flooding is not only related to clay content. In a compact oil reservoir, an oil film inside the reservoir can also serve as a semipermeable membrane, high-salinity primary formation water is contained in reservoir crude oil, after external low-salinity fracturing fluid is contacted with the reservoir crude oil, the low-salinity fracturing fluid is promoted to enter the reservoir interior due to chemical osmotic pressure generated by salinity difference, the imbibition power-chemical osmotic pressure of the reservoir is mainly influenced by salt concentration gradient and oil film viscosity, and the chemical osmotic pressure is increased along with the increase of the salinity gradient. When the fracturing fluid with low mineralization degree enters the reservoir through the oil film, the higher the viscosity of the oil film is, the higher the resistance force penetrating into the reservoir is, and the fracturing fluid with low mineralization degree is difficult to penetrate; when the viscosity of the oil film is reduced, the seepage resistance is reduced, and the seepage efficiency is enhanced.
The third point to be noted is that, by comparing the oil displacement effect of the fracturing fluid under different salinity conditions, under the same reservoir conditions, the imbibition displacement effect decreases with the increase of the salinity of the fracturing fluid, and even is higher than the imbibition displacement efficiency of distilled water under the condition of 2000ppm, because the low mineralized ions act on the rock surface to make the rock surface hydrophilic, and because the concentration difference between the low mineralized ions and the ions in the formation water generates osmotic pressure, the imbibition displacement efficiency is enhanced by the action of the osmotic pressure, so the fracturing fluid with low salinity should be used for enhancing the imbibition displacement effect of the fracturing fluid.
In another possible implementation manner, in order to further study the imbibition displacement process of the fracturing fluid in the formation state, the imbibition displacement effect under the pressurization condition is measured, and a pressurization imbibition displacement manner can also be adopted.
The method comprises the following specific steps:
(1) And measuring the mass of the core sample in the kerosene saturation state to obtain the mass M1 of the core sample.
(2) And placing the core sample in a pressurized saturation device filled with water, and increasing the pressure to 15MPa.
(3) Periodically taking out the core sample, measuring the mass of the core sample at the moment, recording the mass of the core sample at the moment as M2, and showing the oil displacement volume as the following formula:
under the pressurization condition, the time required by imbibition displacement balance is shortened due to the rise of pressure, the displacement rate is obviously improved, but the oil displacement amount is not correspondingly increased.
205. Detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids; and determining the influence data of different types of fracturing fluids on the rock core of the tight oil reservoir to be tested based on the T2 spectrum distribution result.
In the embodiment of the invention, the nuclear magnetic resonance T2 spectral distribution and the evolution of the spectral distribution along with the time can be used for determining the pore size distribution of a compact oil reservoir and the flowing condition of imbibition liquid among large pores and small pores. Among them, ions in the imbibition liquid have an important influence on the flow of microscopic pores. Imbibition liquids with different degrees of mineralization and different ion species affect the double electric layer structure of the rock surface, so that the wettability of the rock surface is changed, and further the oil-water distribution in pores is affected.
Aiming at the step, the pore flow condition of the imbibition liquids of different ion species in the compact sandstone after the crude oil is aged can be monitored through a nuclear magnetic resonance instrument, and the flow rule of the imbibition liquids of different ion species in the microscopic pores is determined. In addition, in order to clarify how the fracturing fluid with low mineralization changes the wettability of the core and to improve the imbibition displacement effect, the following tests were performed based on nuclear magnetic resonance in the embodiment of the present invention.
The method comprises the following steps of detecting a fourth core sample in a plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids, and comprises the following steps:
(1) And carrying out oil washing treatment on the fourth core sample.
The number of the fourth core samples can be 3, for example, 3 tight sandstone blocks can be selected, the core is drilled to be 15mm in length and 25mm in diameter, and then the oil washing treatment is performed.
(2) And soaking the fourth core sample subjected to the oil washing treatment in crude oil of a tight oil reservoir to be tested, and aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time.
The preset temperature may be 50 ℃, and the fourth preset time period may be one week, which is not specifically limited in the embodiment of the present invention. Illustratively, the fourth core sample is soaked in crude oil and aged at a temperature of 50 ℃, and after one week of aging, the fourth core sample is removed.
(3) Based on a fifth preset time, putting the taken out fourth core sample into a plurality of fracturing fluids of different types for imbibition displacement, wherein one type of fracturing fluid is provided with one core sample; and obtaining the T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids based on nuclear magnetic resonance.
The fifth preset time period may be one week, which is not specifically limited in the embodiment of the present invention. Illustratively, taking the number of core samples as 3, the removed core samples may be placed in a solution containing 2000ppm nacl, 50000ppm nacl, and 2000ppm cacl2, respectively, to continuously monitor the T2 distribution of the core samples.
It should be noted that, through the T2 distribution evolution diagram of the fracturing fluid imbibed by the core sample with different mineralization or salinity, the change of the T2 spectrum peak after imbibing different time can be determined. The short relaxation peak value of the low-mineralization-degree monovalent ion fracturing fluid is increased greatly in the imbibition displacement process, the relaxation time of the peak value drifts slightly to the left, and a long relaxation peak value appears in the imbibition displacement process and the peak value is slightly increased; in the process of imbibition displacement, the high-salinity monovalent ion fracturing fluid gradually changes from a starting single-peak structure into a double-peak structure, the short relaxation peak value increases, the relaxation time of the peak value drifts to the right, the long relaxation peak value also continuously increases, and the relaxation time of the peak value also drifts to the right; in the process of imbibition displacement, the T2 spectrogram change of the divalent ion fracturing fluid with low mineralization degree is similar to the T2 spectrogram of the monovalent ion fracturing fluid with high mineralization degree.
In conclusion, when the core sample in an oil saturation state is imbibed and displaced by the low-mineralization-degree monovalent ion fracturing fluid, the short relaxation increases rapidly, and water enters the pore surface of the core sample, so that the low-mineralization-degree fracturing fluid can change the wettability of the surface of the core and strengthen the hydrophilic characteristic of the surface. When a rock core sample in an oil saturation state is imbibed and displaced by using a fracturing fluid with high salinity and a divalent ion fracturing fluid with low salinity, the long relaxation is increased quickly, water enters the middle part of a rock pore and is reduced in contact with the surface of the rock, and the hydrophilic characteristic of the water is not exerted.
The method provided by the embodiment of the invention realizes the wetting performance test of the core sample of the compact oil reservoir to be tested to judge the hydrophilicity of the core sample, obtains the imbibition and diffusion capacity of the core sample by utilizing the imbibition performance test, analyzes the influence of different types of fracturing fluids on the oil displacement potential of the compact oil reservoir by utilizing the imbibition displacement test, detects the change of different types of fracturing fluids on the core sample by utilizing nuclear magnetic resonance, confirms the interaction between the compact oil reservoir and the fracturing fluids by the test, determines the energy storage and displacement performance of the compact oil, can accurately analyze the oil displacement potential of the compact oil reservoir and the influence of different types of fracturing fluids on the imbibition displacement potential, and realizes better analysis and test of the compact oil reservoir from microscopic pores.
In another embodiment, the invention is further explained below with reference to a specific embodiment.
Illustratively, core samples from two wells, the flat 9 and 59 wells, were taken for wettability testing, and the results showed that the Cha Ping wells were more hydrophilic than the 59 wells. The rock core of the compact oil reservoir is basically a low-energy surface, has strong hydrophilicity and strong adsorption capacity to organic matters, and the surface of the reservoir is easy to adsorb the organic matters in the process of imbibition displacement, so that the imbibition displacement efficiency is reduced.
And performing spontaneous imbibition test on core samples of the two wells, namely the flat-checking 9 well and the 59 well, to obtain a secondary root graph of the imbibition amount and time, wherein the imbibition segment speed of the flat-checking 9 well is obviously higher than that of the 59 well, and the hydrophilicity of the flat-checking 9 well is consistent with that of the 59 well. The diffusion zone of the well under investigation 59 had a longer imbibition time and a larger imbibition volume than the well under investigation 9. This indicates that the cores of the 59 well examined contained relatively high levels of clay minerals. Comparing the pore structure of two wells, looking for 59 wells the hole is more, and the hole distribution of looking for flat 9 wells is less and little, all distributes the clay mineral of different degree around the hole of two kinds of rock cores, and after it contacted with water, launching can slowly be inhaled in the rock under the effect of capillary force and osmotic pressure.
And carrying out imbibition, drainage and flooding tests on core samples of two wells, namely a horizontal well 9 and a 59 well 59, drawing a change curve of oil displacement efficiency along with time according to data obtained by the tests, wherein the change curve can be used for obtaining that the oil displacement percentages of the two cores are reduced along with the increase of the mineralization degree of the fracturing fluid on the whole, and the oil displacement efficiency in the low-concentration divalent ion fracturing fluid is less than that of the low-concentration NaCl solution. The oil displacement efficiency of the exploration 9 well in the low-concentration NaCl solution is higher than that of the exploration 59 well in the low-concentration NaCl solution. In addition, measuring the seepage displacement effect of the core sample of Cha Ping well and the checking 59 well under the pressurizing condition to obtain the corresponding relation between the oil displacement efficiency and the time of the core sample in the fracturing fluid after the core sample is soaked in kerosene, and obtaining the conclusion of checking the oil displacement capacity of the level 9 well and the checking 59 well according to the corresponding relation.
And (3) monitoring the change of the core wettability by adopting nuclear magnetic resonance to displace a saturated crude oil core sample by infiltration and absorption under low mineralization degree. The well finding 9 and the well finding 59 use fracturing fluid with the same mineralization degree to displace crude oil, and the short relaxation increase of the well finding 59 is faster than that of the well finding 9, the short relaxation peak increase is larger than that of the well finding 9, the relaxation time of the peak slightly shifts to the left, and a long relaxation peak appears and the peak slightly increases in the imbibition displacement process according to the obtained T2 map. When a saturated rock core sample is displaced by using the low-mineralization-degree monovalent fracturing fluid through imbibition, the short relaxation is increased quickly, and water enters the surface of the pore of the rock core, so that the low-mineralization-degree fracturing fluid can change the wettability of the surface of the rock core and strengthen the hydrophilic characteristic of the surface. When a saturated rock core sample is imbibed and displaced by divalent ion fracturing fluid with high mineralization and low mineralization, long relaxation is increased quickly, water enters the middle of the rock pore and is reduced in contact with the surface of the rock, and the hydrophilic characteristic of the water is not exerted.
Fig. 3 is a schematic structural diagram of a system for determining a dense oil energy storage displacement performance according to an embodiment of the present invention. Referring to fig. 3, the system includes: a first device 301, a second device 302, a third device 303, and a fourth device 304;
the first device 301 is configured to perform a wettability test on a first core sample in a plurality of core samples to obtain hydrophilic performance data of a core of a tight oil reservoir to be tested, where the plurality of core samples are cores from at least one oil well of the tight oil reservoir to be tested;
a second device 302, configured to perform imbibition performance testing on a second core sample in the multiple core samples, so as to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested;
a third device 303, configured to perform an imbibition oil displacement test on a third core sample in the multiple core samples to obtain data of influence of different types of fracturing fluids on oil displacement performance of the tight oil reservoir to be tested;
a fourth device 304, configured to detect a fourth core sample of the multiple core samples based on nuclear magnetic resonance, obtain a T2 spectrum distribution result of the fourth core sample in different types of fracturing fluids, and determine influence data of the different types of fracturing fluids on a core of the tight oil reservoir to be tested based on the T2 spectrum distribution result.
The system provided by the embodiment of the invention realizes the wetting performance test of the core sample of the compact oil reservoir to be tested to judge the hydrophilicity of the core sample, obtains the imbibition and diffusion capacity of the core sample by utilizing the imbibition performance test, analyzes the influence of different types of fracturing fluids on the oil displacement potential of the compact oil reservoir by utilizing the imbibition displacement test, detects the change of different types of fracturing fluids on the core sample by utilizing nuclear magnetic resonance, confirms the interaction between the compact oil reservoir and the fracturing fluids by the test, determines the compact oil energy storage displacement performance, can accurately analyze the oil displacement potential of the compact oil reservoir and the influence of different types of fracturing fluids on the imbibition displacement potential, and realizes better analysis and test of the compact oil reservoir from microscopic pores.
In a possible implementation manner, the first device 301 is further configured to perform a wetting angle test on the first core sample to obtain a moisture wetting angle and an oil-gas wetting angle change, and obtain hydrophilic performance data of the core of the tight oil reservoir to be tested based on the moisture wetting angle and the oil-gas wetting angle change, where crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or performing wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; and repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data.
In a possible implementation manner, the second apparatus 302 is further configured to dry the second core sample at a preset temperature for a first preset time; obtaining the mass of the cooled second core sample; immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-absorbent fine wire; obtaining the mass of the second core sample in different time; and acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-absorption section and a diffusion self-absorption section.
In a possible implementation manner, the third device 303 is further configured to perform oil washing processing on the third core sample; soaking the third core sample subjected to oil washing treatment in kerosene; performing pressurization saturation treatment on the third core sample soaked in the kerosene based on preset pressure and second preset time; based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; and acquiring oil displacement data matched with the different types of fracturing fluids, and acquiring influence data of the different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data.
In a possible implementation manner, the fourth device 304 is further configured to perform an oil washing process on the fourth core sample; soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested; aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time; based on a fifth preset time, putting the taken fourth core sample into a plurality of different types of fracturing fluids for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
All the above optional technical solutions may be combined arbitrarily to form the optional embodiments of the present disclosure, and are not described herein again.
It should be noted that: in the system for determining the compact oil energy storage and replacement performance provided by the embodiment, when determining the compact oil energy storage and replacement performance, only the division of the functional devices is taken as an example, and in practical application, the functions may be distributed to different functional devices according to needs, that is, the internal structure of the system may be divided into different functional devices to complete all or part of the functions described above. In addition, the system for determining the energy storage and replacement performance of the dense oil and the method embodiment for determining the energy storage and replacement performance of the dense oil provided by the embodiments belong to the same concept, and specific implementation processes thereof are detailed in the method embodiment and are not described herein again.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (2)
1. A method of determining a tight oil energy storage displacement performance, the method comprising:
performing a wettability test on a first core sample in a plurality of core samples to obtain hydrophilic performance data of a core of a tight oil reservoir to be tested, wherein the plurality of core samples are cores derived from at least one oil well of the tight oil reservoir to be tested;
performing liquid absorption performance test on a second core sample in the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested;
carrying out an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested;
detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids;
determining influence data of the different types of fracturing fluids on the core of the tight oil reservoir to be tested based on the T2 spectrum distribution result;
the method for testing the wettability of the first core sample in the plurality of core samples to obtain the hydrophilic performance data of the core of the tight oil reservoir to be tested comprises the following steps:
carrying out wetting angle test on the first core sample to obtain a water-gas wetting angle and oil-gas wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested on the basis of the water-gas wetting angle and the oil-gas wetting angle change, wherein crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data; or the like, or a combination thereof,
carrying out wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the compact oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data;
the method for testing the imbibition performance of the second core sample in the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested comprises the following steps:
drying the second core sample for a first preset time at a preset temperature;
obtaining the mass of the cooled second core sample;
immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-water-absorbing fine line;
obtaining the mass of the second core sample in different time;
acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-priming section and a diffusion self-priming section;
performing an imbibition displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the displacement performance of the tight oil reservoir to be tested, wherein the influence data comprises:
performing oil washing treatment on the third core sample;
soaking the third core sample subjected to oil washing treatment in kerosene;
performing pressurization saturation treatment on the third core sample soaked in the kerosene based on preset pressure and second preset time;
based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
acquiring oil displacement data matched with the different types of fracturing fluids, and acquiring influence data of the different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data;
the detecting of the fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain the T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids includes:
performing oil washing treatment on the fourth core sample;
soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested;
aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time;
based on a fifth preset time, placing the taken out fourth core sample in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid;
and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
2. A system for determining a tight oil energy storage displacement performance, the system comprising: a first device, a second device, a third device, and a fourth device;
the first device is used for carrying out wettability test on a first core sample in a plurality of core samples to obtain hydrophilic performance data of a core of a tight oil reservoir to be tested, wherein the plurality of core samples are cores derived from at least one oil well of the tight oil reservoir to be tested;
the second device is used for carrying out imbibition performance test on a second core sample in the plurality of core samples to obtain imbibition data and diffusion data of the core of the tight oil reservoir to be tested;
the third device is used for carrying out an imbibition oil displacement test on a third core sample in the plurality of core samples to obtain influence data of different types of fracturing fluids on the oil displacement performance of the tight oil reservoir to be tested;
the fourth device is used for detecting a fourth core sample in the plurality of core samples based on nuclear magnetic resonance to obtain T2 spectrum distribution results of the fourth core sample in different types of fracturing fluids, and determining influence data of the different types of fracturing fluids on the core of the tight oil reservoir to be tested based on the T2 spectrum distribution results;
the first device is further used for testing a wetting angle of the first core sample to obtain a water-gas wetting angle and oil-gas wetting angle changes, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested based on the water-gas wetting angle and the oil-gas wetting angle changes, wherein crude oil and distilled water exist on the surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving an average value of the obtained hydrophilic performance data; or performing wetting angle test on the first core sample to obtain water-oil wetting angle change, and obtaining hydrophilic performance data of the core of the tight oil reservoir to be tested based on the water-oil wetting angle change, wherein the first core sample is soaked in water and crude oil exists on the lower surface of the first core sample; repeatedly executing the wetting angle test for a preset number of times, and solving the average value of the obtained hydrophilic performance data;
the second device is further used for drying the second core sample for a first preset time at a preset temperature; obtaining the mass of the cooled second core sample; immersing the cooled second core sample in fracturing fluid, wherein the second core sample is suspended in the fracturing fluid through an inelastic and non-absorbent fine wire; obtaining the mass of the second core sample in different time; acquiring a imbibition characteristic curve of the second core sample based on the change of the mass of the second core sample along with time, wherein the imbibition characteristic curve comprises a capillary self-priming section and a diffusion self-priming section;
the third device is also used for carrying out oil washing treatment on the third core sample; soaking the third core sample subjected to oil washing treatment in kerosene; performing pressurization saturation treatment on the third core sample soaked in the kerosene based on a preset pressure and a second preset time; based on a third preset time, placing the third core sample after being taken out in fracturing fluids of different types for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; acquiring oil displacement data matched with the fracturing fluids of different types, and acquiring influence data of the fracturing fluids of different types on the oil displacement performance of the tight oil reservoir to be tested based on the oil displacement data;
the fourth device is also used for carrying out oil washing treatment on the fourth core sample; soaking the fourth core sample subjected to oil washing treatment in the crude oil of the tight oil reservoir to be tested; aging the crude oil soaked with the fourth core sample based on a preset temperature and a fourth preset time; based on a fifth preset time, putting the taken fourth core sample into a plurality of different types of fracturing fluids for imbibition displacement, wherein one core sample is placed in one type of fracturing fluid; and acquiring the T2 spectrum distribution result of the fourth core sample in the different types of fracturing fluids based on nuclear magnetic resonance.
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