CN116067842A - Method, device and storage medium for monitoring wettability of rock core - Google Patents
Method, device and storage medium for monitoring wettability of rock core Download PDFInfo
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- CN116067842A CN116067842A CN202310009099.0A CN202310009099A CN116067842A CN 116067842 A CN116067842 A CN 116067842A CN 202310009099 A CN202310009099 A CN 202310009099A CN 116067842 A CN116067842 A CN 116067842A
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- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N13/00—Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
Abstract
The application discloses a method, a device and a storage medium for monitoring wettability of a rock core. The method comprises the following steps: acquiring a set of oil-water-solid distribution images of a plurality of detection periods of the core, wherein the set of oil-water-solid distribution images of any detection period comprises a preset number of oil-water-solid distribution images; for any detection period, determining a plurality of three-phase boundary points in the oil-water-solid distribution image through a three-phase boundary point identification model; determining a contact angle corresponding to each three-phase junction point; determining wettability of the contact angle according to preset conditions; and outputting wettability data corresponding to the oil-water-solid distribution image set to determine wettability change conditions of the rock core, wherein the wettability data comprises the total number of contact angles and the ratio of contact angles under different wettabilities. The rock core wettability monitoring method and device can be suitable for monitoring rock core wettability changes in the displacement process under different development technologies, and output shows rock surface wettability changes under different development modes, so that the application range is wide, and the efficiency and accuracy of contact angle identification are improved.
Description
Technical Field
The application relates to the technical field of oil and gas field development of petroleum engineering, in particular to a method, a device and a storage medium for monitoring wettability of a rock core.
Background
In the oil reservoir development process, rock wettability has important significance for the distribution and quantity of residual oil. In the period of continuous iterative updating of the thickened oil thermal recovery development technology, the multi-element hot fluid compound flooding technology has been widely applied. The wettability change effect of the rock surface is obvious under the influence of high temperature and external fluid. How to embody such wettability has become a hot spot field of rock property change in the current research and development process.
How to observe wettability changes during displacement using visual means is becoming an important issue of research. And part of scholars use the two-dimensional visual sand filling model or the etching model and other plane visual models and use the optical instrument to capture the position and quantity change of thick oil on the rock wall surface in the development process, so as to judge the change condition of wettability. In particular, some scholars have classified various types of remaining oils, such as lamellar oil, drip oil, membranous oil, and columnar oil, etc., by various intelligent optimization algorithms. However, the two-dimensional visual sand filling model and the etching model are difficult to simulate the rock framework and cementing environment of a real reservoir, and are not beneficial to research on the change of wettability of the reservoir under the conditions of high temperature and chemical agent.
The most common way of expressing rock wettability is currently to use the contact angle to reflect directly, in this respect, some scholars propose to use intelligent recognition algorithms to improve the detection efficiency. Patent 202110276414.7 proposes an in-situ contact angle measuring device and a contact angle determining method based on deep learning, wherein the method is only suitable for measuring the contact angle value of a conventional flat core surface under static conditions, and the shape of the contact angle is complete. In addition, some research papers propose to calculate the contact angle by using a semi-supervised algorithm, but related algorithms are easy to miscalculate the fluctuation angle of various non-adsorptivity residual oils such as flake-shaped and columnar residual oils in the rock pores as the contact angle, so that the quantity and the size of the contact angle are influenced. The method proposed by the patent has too high requirements on the contact angle of the test, and cannot fully meet the measurement requirements on the contact angle of the rock surface in the displacement experiment.
Therefore, the method for monitoring the change of the wettability of the rock core in the displacement process adopted in the prior art has the problems of smaller application range and lower precision.
Disclosure of Invention
An object of the embodiment of the application is to provide a method, a device and a storage medium for monitoring wettability of a core, which are used for solving the problems of smaller application range and lower precision of a method for monitoring wettability change of the core in a displacement process adopted in the prior art.
To achieve the above object, a first aspect of the present application provides a method for monitoring wettability of a core, including:
acquiring a set of oil-water-solid distribution images of a plurality of detection periods of the core, wherein the set of oil-water-solid distribution images of any detection period comprises a preset number of oil-water-solid distribution images;
for any detection period, determining a plurality of three-phase boundary points in the oil-water-solid distribution image through a three-phase boundary point identification model;
respectively determining a contact angle corresponding to each three-phase junction point;
determining wettability of the contact angle according to preset conditions;
determining wettability data corresponding to the oil-water-solid distribution image set;
outputting wettability data corresponding to the oil-water-solid distribution image set to determine wettability change conditions of the rock core;
wherein the wettability data comprises the total number of contact angles and the ratio of contact angles at different wettabilities.
In an embodiment of the present application, acquiring a set of oil-water-solid distribution images of a plurality of detection periods of a core includes:
scanning the rock core according to a preset period in the process of injecting the displacement fluid so as to obtain a preset number of scanning images of a plurality of detection periods;
processing the scanned image to distinguish oil-water-solid three phases in the scanned image and obtain an initial oil-water-solid distribution image;
Performing color correction treatment on the initial oil-water-solid distribution image to obtain a treated image, wherein oil-water-solid phases in the treated image are respectively distinguished by different color representations;
and performing edge detection on the processed image to obtain a set of oil-water-solid distribution images with a plurality of detection periods.
In the embodiment of the present application, the preset period is set according to the increasing volume of the injected displacement fluid, and the preset number of scanned images are scanned images of the end faces of different positions of the core respectively.
In this embodiment of the present application, determining the contact angle corresponding to each three-phase boundary point includes:
for any three-phase boundary point, acquiring the total pixel area of a set area corresponding to the any three-phase boundary point, wherein the set area is a circular area formed by taking the any three-phase boundary point as a circle center and taking a preset distance as a radius;
acquiring the water phase pixel area occupied by the water phase area in the set area;
and determining the contact angle corresponding to any three-phase junction point according to the water phase pixel area and the total pixel area.
In the embodiment of the application, the contact angle corresponding to any three-phase boundary point satisfies the following formula:
wherein θ is the contact angle corresponding to the three-phase boundary point, S wet Is the area of the water phase pixel, S total Is the total pixel area.
In an embodiment of the present application, determining the wettability of the contact angle according to the preset condition includes:
when the contact angle is smaller than the first threshold value, judging that the wettability of the contact angle is oleophilic;
in the case where the contact angle is greater than or equal to the first threshold value and less than or equal to the second threshold value, determining that the wettability of the contact angle is neutral wetting;
when the contact angle is larger than the second threshold value, the wettability of the contact angle is determined to be hydrophilic.
In an embodiment of the present application, the method further includes:
acquiring a training data set and a verification data set;
training an initial three-phase boundary point identification model through a training data set to obtain a trained three-phase boundary point identification model;
and inputting the verification data set into the trained three-phase boundary point identification model to obtain the three-phase boundary point identification model.
In an embodiment of the present application, the training data set and the verification data set each include data related to a plurality of contact angles, and the data related to each contact angle includes a first coordinate, a second coordinate, and a size of the contact angle.
A second aspect of the present application provides an apparatus for monitoring wettability of a core, comprising:
a memory configured to store instructions; and
The processor is configured to call instructions from the memory and when executing the instructions can implement the method for monitoring core wettability described above.
A third aspect of the present application provides a machine-readable storage medium having stored thereon instructions for causing a machine to perform the above-described method for monitoring core wettability.
According to the technical scheme, the oil-water-solid distribution image set of a plurality of detection periods of the rock core is obtained firstly, then for any detection period, a plurality of three-phase junctions in the oil-water-solid distribution image are determined through the three-phase junction identification model, the contact angle corresponding to each three-phase junction is respectively determined, the wettability of the contact angle is determined according to preset conditions, and finally wettability data corresponding to the oil-water-solid distribution image set are output to determine the wettability change condition of the rock core, wherein the wettability data comprise the total number of the contact angles and the ratio of the contact angles under different wettabilities. The rock core wettability monitoring method and device can be suitable for monitoring rock core wettability changes in the displacement process under different development technologies, and output shows rock surface wettability changes under different development modes, so that the application range is wide, and the efficiency and accuracy of contact angle identification are improved.
Additional features and advantages of embodiments of the present application will be set forth in the detailed description that follows.
Drawings
The accompanying drawings are included to provide a further understanding of embodiments of the present application and are incorporated in and constitute a part of this specification, illustrate embodiments of the present application and together with the description serve to explain, without limitation, the embodiments of the present application. In the drawings:
fig. 1 is a schematic structural diagram of a core model displacement device according to an embodiment of the present application;
FIG. 2 is a schematic flow chart of a method for monitoring wettability of a core according to an embodiment of the present disclosure;
FIG. 3 is a schematic diagram of a full flow process for determining contact angle according to an embodiment of the present application;
fig. 4 is a block diagram of an apparatus for monitoring wettability of a core according to an embodiment of the present application.
Description of the reference numerals
11. Flow control amount of carbon dioxide cylinder 12
13. Steam generator 14 injection two-way valve
15. High-precision double-cylinder plunger pump 16 intermediate container
17. Six-way valve 18 open-flow measuring cylinder
21. Core holder 22 back pressure valve
23. High-precision single-cylinder plunger pump 24 incubator
31. Computer 32 electronic pressure gauge
33. Electronic balance
Detailed Description
For the purposes of making the objects, technical solutions and advantages of the embodiments of the present application more clear, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it should be understood that the specific implementations described herein are only for illustrating and explaining the embodiments of the present application, and are not intended to limit the embodiments of the present application. All other embodiments, which can be made by one of ordinary skill in the art without undue burden from the present disclosure, are within the scope of the present application based on the embodiments herein.
It should be noted that, in the embodiment of the present application, directional indications (such as up, down, left, right, front, and rear … …) are referred to, and the directional indications are merely used to explain the relative positional relationship, movement conditions, and the like between the components in a specific posture (as shown in the drawings), and if the specific posture is changed, the directional indications are correspondingly changed.
In addition, if there is a description of "first", "second", etc. in the embodiments of the present application, the description of "first", "second", etc. is for descriptive purposes only and is not to be construed as indicating or implying a relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defining "a first" or "a second" may explicitly or implicitly include at least one such feature. In addition, the technical solutions of the embodiments may be combined with each other, but it is necessary to base that the technical solutions can be realized by those skilled in the art, and when the technical solutions are contradictory or cannot be realized, the combination of the technical solutions should be regarded as not exist and not within the protection scope of the present application.
Fig. 1 is a schematic structural diagram of a core model displacement device according to an embodiment of the present application. As shown in fig. 1, the embodiment of the application provides a core model displacement device, which provides a material basis for monitoring the wettability change of a core, and comprises a carbon dioxide gas cylinder 11, a gas flow control amount 12, a steam generator 13, an injection two-way valve 14, a high-precision double-cylinder plunger pump 15, an intermediate container 16, a six-way valve 17, a blowout measuring cylinder 18, a core holder 21, a back pressure valve 22, a high-precision single-cylinder plunger pump 23, a constant temperature box 24, a computer 31, an electronic pressure gauge 32 and an electronic balance 33. The following stages are completed before the displacement experiment begins.
Firstly, assembling a core displacement experimental device, wherein the displacement experimental device comprises a multi-element displacement system, a core model system and a displacement dynamic monitoring system; then constructing a multi-element displacement system, connecting the high-precision double-cylinder plunger pump 15 with the injection end of the intermediate container 16, and then connecting the intermediate container 16 with the six-way valve 17; the six-way valve 17 is connected with the intermediate container 16, the non-condensate gas cylinder, the gas flow rate control meter, the electronic pressure gauge, the vent pipeline and the output port pipeline in sequence. Then, the core model system is to put the core to be observed in a core holder 21, then put the core holder 21 in an incubator 24, and the tail of the core holder 21 is connected with a back pressure valve 22; the pressurizing port of the back pressure valve 22 is connected with a high-precision single-cylinder plunger pump 23, so as to require the outlet end of the core to maintain certain stratum pressure; the outlet end of the back pressure valve 22 is connected with a measuring cylinder for measuring the liquid amount of produced liquid, and the construction of the core model system is completed.
Further, a displacement dynamic monitoring system is built, wherein an injection end electronic pressure gauge data line connected with the six-way valve 17 is connected with a computer 31, and dynamic data transmission of injection end pressure is completed; further, an electronic balance is placed below the measuring cylinder at the outlet end and connected with the computer 31, so that dynamic data transmission of output at the outlet end is completed, and the assembly of the rock core displacement experimental device is completed. After the core is placed, all valves are closed, the pressure of a single-cylinder plunger pump is increased to the pressure of a target reservoir, a nitrogen cylinder is connected with an emptying pipeline, the emptying pipeline valve of the six-way valve 17 is opened, the nitrogen cylinder is opened to perform air tightness detection of a displacement experiment device, and a displacement experiment is performed after no leakage point is detected.
Further, setting the temperature of the incubator 24 as a target temperature, opening a valve of the water phase intermediate container 16 of the six-way valve 17 after the temperature in the core holder 21 reaches the target temperature, starting the high-precision double-cylinder plunger pump 15, performing saturated water work at a target flow rate, calculating the liquid phase permeability of the core according to Darcy's law, calculating the effective porosity of the core by dividing the difference between the injected water volume and the produced water volume by the apparent volume of the core until the outlet end of the back pressure valve 22 stably produces water, and completing the saturated water stage. Then, the valve of the water phase intermediate container 16 of the six-way valve 17 is closed, the valve of the oil phase intermediate container 16 of the six-way valve 17 is opened, saturated water work is carried out at a target flow rate until the outlet end of the back pressure valve 22 is used for stably producing oil, a saturated oil stage is completed, the initial oil saturation is calculated according to the difference between the injected oil volume and the produced oil divided by the apparent volume of the core, the difference between the effective porosity and the initial oil saturation is recorded as the initial water saturation, and the saturated oil stage is completed. Then, all valves are closed, and the core completed with saturated oil is aged in the incubator 24 which is set to the target temperature for more than 72 hours, so that the construction of the simulated oil reservoir is completed. Finally, the valve of the six-way valve 17 where the displacement fluid is located is opened, and a displacement experiment is carried out by mixing and injecting the displacement fluid or alternatively injecting the displacement fluid at a target flow rate according to the displacement design requirement.
Fig. 2 is a schematic flow chart of a method for monitoring wettability of a core according to an embodiment of the present application. As shown in fig. 2, an embodiment of the present application provides a method for monitoring wettability of a core, which may include the following steps:
102, for any detection period, determining a plurality of three-phase boundary points in the oil-water-solid distribution image through a three-phase boundary point identification model;
104, determining wettability of the contact angle according to preset conditions;
wherein the wettability data comprises the total number of contact angles and the ratio of contact angles at different wettabilities.
In the embodiment of the application, wettability is the characteristic of the surface of a material, reflects complex physical and chemical reaction of a phase interface, and has important influence on fluid distribution and phase interface movement in pores. In the oil reservoir development process, rock wettability has important significance for distribution and quantity of residual oil, and the change condition of the rock wettability can be directly reflected through a contact angle. The contact angle is the most main physical quantity for describing the wettability of a liquid-solid interface, and has wide effects on the aspects of surface chemistry, chemical production, material preparation, petrochemical industry, environmental protection and the like. Thus, the change in core wettability can be determined by measuring the contact angle of the rock surface during displacement.
In the embodiment of the application, the rock core can be scanned at intervals of a preset period in the displacement experiment process, so that the oil-water-solid distribution image set of the rock core under a plurality of detection periods is obtained. The oil-water-solid distribution image is an image containing the distribution condition of oil phase, solid phase and water phase, and is obtained by scanning a rock core. The preset period refers to a time period during which the core is scanned to obtain the oil-water-solid distribution image during the displacement process, in one example, the preset period may be set according to an increase volume of the displacement fluid injected during the displacement experiment, for example, the preset period may be 25PV, and the core is scanned once every 25PV increase of the volume of the displacement fluid to obtain an oil-water-solid distribution image set, where 1PV means that the volume of the injected displacement fluid reaches a core pore volume. The oil-water-solid distribution image set corresponding to each detection period comprises a preset number of oil-water-solid distribution images. In one example, the preset number of scan images are scan images of end faces of different positions of the core respectively, and the specific value of the preset number can be determined according to the length of the core in combination with actual requirements, for example, the length of the core is 5 cm, the preset number can be 6, the displacement fluid injection volume node is taken as a scan point, one scan image is obtained by scanning every one cm, 6 scan images are obtained in total, and 6 oil-water solid distribution images are obtained after processing, so that an oil-water solid distribution image set is formed. Therefore, sufficient image data can be provided for monitoring the wettability change of the core, and the accuracy of the monitoring result of the wettability change of the core is improved.
In the embodiment of the application, the three-phase boundary point refers to a point where an oil-water phase and a solid-phase three-phase in the oil-water-solid distribution image intersect. The contact angle refers to the included angle between the solid-liquid interface and the gas-liquid interface from the inside of the liquid at the junction of the solid phase, the liquid phase and the gas phase, namely the included angle between the liquid-solid interface and the tangent line of the liquid surface at the contact point of the liquid phase and the solid phase. Therefore, in the case of determining the three-phase boundary point, the contact angle corresponding to the three-phase boundary point can be determined. Specifically, after the collection of the oil-water-solid distribution images under each detection period is obtained, for each detection period, a plurality of three-phase junctions in each oil-water-solid distribution image can be determined through the three-phase junction identification model. In one example, a three-phase junction recognition model may be constructed based on a convolutional neural network. Further, the contact angle corresponding to each three-phase boundary point is determined based on the oil-water-solid distribution image, and then the wettability of the contact angle is determined according to preset conditions. In one example, the preset condition refers to dividing wettability of the contact angle according to a range interval in which the angle of the contact angle is located, and the wettability may be classified into three types of lipophilicity, neutral wetting and hydrophilicity. Similarly, all contact angles in the oil-water-solid distribution image set under each detection period and the wettability of each contact angle can be determined, and then the wettability data of the oil-water-solid distribution image set of each detection period can be statistically determined. Wettability data of the oil-water-solid distribution image set of each detection period are respectively output, and according to the data, wettability change conditions of the rock core can be realized. The wettability data corresponding to any detection period comprises the total number of contact angles in the oil-water solid distribution image set and the proportion of the number of contact angles with different wettabilities in the detection period to the total number of contact angles.
According to the technical scheme, the oil-water-solid distribution image set of a plurality of detection periods of the rock core is obtained firstly, then for any detection period, a plurality of three-phase junctions in the oil-water-solid distribution image are determined through the three-phase junction identification model, the contact angle corresponding to each three-phase junction is respectively determined, the wettability of the contact angle is determined according to preset conditions, and finally wettability data corresponding to the oil-water-solid distribution image set are output to determine the wettability change condition of the rock core, wherein the wettability data comprise the total number of the contact angles and the ratio of the contact angles under different wettabilities. The rock core wettability monitoring method and device can be suitable for monitoring rock core wettability changes in the displacement process under different development technologies, and output shows rock surface wettability changes under different development modes, so that the application range is wide, and the efficiency and accuracy of contact angle identification are improved.
In an embodiment of the present application, acquiring a set of oil-water-solid distribution images of a plurality of detection periods of a core may include:
scanning the rock core according to a preset period in the process of injecting the displacement fluid so as to obtain a preset number of scanning images of a plurality of detection periods;
processing the scanned image to distinguish oil-water-solid three phases in the scanned image and obtain an initial oil-water-solid distribution image;
Performing color correction treatment on the initial oil-water-solid distribution image to obtain a treated image, wherein oil-water-solid phases in the treated image are respectively distinguished by different color representations;
and performing edge detection on the processed image to obtain a set of oil-water-solid distribution images with a plurality of detection periods.
In the embodiment of the application, after a displacement experiment is started, the displacement fluid is continuously injected into the core, and in order to better detect the wettability change condition of the core in the displacement process, the core can be scanned according to a preset period in the displacement fluid injection process so as to obtain a scanning image of the core. The preset period refers to a time period of scanning the core during the displacement process to obtain an oil-water-solid distribution image, in one example, the preset period may be set according to an increase volume of the displacement fluid injected during the displacement experiment, for example, the preset period may be 25PV, and each time the volume of the displacement fluid increases by 25PV, the core is scanned to obtain an oil-water-solid distribution image set, where 1PV refers to that the volume of the injected displacement fluid reaches a core pore volume. Therefore, a plurality of scanning image sets corresponding to the detection periods can be obtained, and each scanning image set contains a preset number of scanning images. The preset number of scanning images are respectively scanning images of end faces of different positions of the core, and specific numerical values of the preset number can be determined according to the length of the core and the actual requirements. In one example, the rock core can be scanned by a CT scanner, and the CT computer scanning technology can truly reflect the actual change of the oil-water distribution of the rock core in the displacement process, so that the rock core is a suitable platform for expressing the rock wettability change in the displacement process. The CT computer scanning technology is used as a currently accepted main method for reflecting the real structure of the rock core, and is also one of the most direct and most accurate methods for establishing the microscopic pore structure of the rock. Meanwhile, the CT imaging method has the advantages of simple operation, high precision, capability of realizing nondestructive detection and the like, and is widely applied to research on microscopic features and seepage mechanisms of porous media.
In the embodiment of the application, after a preset number of scanned images corresponding to a plurality of detection periods are obtained through scanning, the scanned images can be selected by using aviZO software three-dimensional visualization processing software, and oil-water-solid phases in the scanned images are distinguished by adopting modes such as surface rendering processing and the like so as to obtain an initial oil-water-solid distribution image. Further, color correction can be performed on the initial oil-water-solid distribution image, and the oil-water-solid phases in the initial oil-water-solid distribution image are respectively distinguished by different colors, namely each image contains three different colors. And finally, carrying out edge detection on the processed image to highlight the position and distribution difference of the oil-water two phases on the rock wall surface so as to obtain an oil-water solid distribution image. Repeating the above operation to obtain the oil-water-solid distribution image set corresponding to each of the detection periods. Therefore, sufficient basic image data can be provided for monitoring the wettability change of the core, and the accuracy of the monitoring result of the wettability change of the core is improved.
In the embodiment of the present application, the preset period is set according to the increasing volume of the injected displacement fluid, and the preset number of scanned images are scanned images of the end faces of different positions of the core respectively.
In the embodiment of the present application, the preset period refers to a time period during which the core is scanned to obtain the oil-water-solid distribution image during the displacement process, and in one example, the preset period may be set according to an increasing volume of the displacement fluid injected during the displacement experiment, for example, the preset period may be 25PV, and then the core is scanned once every 25PV of the volume of the displacement fluid increases to obtain a set of oil-water-solid distribution images, where 1PV refers to that the volume of the injected displacement fluid reaches a core pore volume. The preset number of scanning images are respectively scanning images of end faces of different positions of the rock core, the specific numerical value of the preset number can be determined according to the length of the rock core and the actual requirement, for example, the length of the rock core is 5 cm, the preset number can be 6, displacement fluid injection volume nodes are taken as scanning points, one scanning image is obtained by scanning every other cm, 6 scanning images are obtained in total, and 6 oil-water solid distribution images are obtained after processing, so that an oil-water solid distribution image set is formed. Therefore, sufficient image data can be provided for monitoring the wettability change of the core, and the accuracy of the monitoring result of the wettability change of the core is improved.
In an embodiment of the present application, determining the contact angle corresponding to each three-phase boundary point respectively may include:
for any three-phase boundary point, acquiring the total pixel area of a set area corresponding to the any three-phase boundary point, wherein the set area is a circular area formed by taking the any three-phase boundary point as a circle center and taking a preset distance as a radius;
acquiring the water phase pixel area occupied by the water phase area in the set area;
and determining the contact angle corresponding to any three-phase junction point according to the water phase pixel area and the total pixel area.
In the embodiment of the application, the three-phase boundary point refers to a point where an oil-water phase and a solid-phase three-phase in the oil-water-solid distribution image intersect. The contact angle refers to the included angle between the solid-liquid interface and the gas-liquid interface from the inside of the liquid at the junction of the solid phase, the liquid phase and the gas phase, namely the included angle between the liquid-solid interface and the tangent line of the liquid surface at the contact point of the liquid phase and the solid phase. Therefore, in the case of determining the three-phase boundary point, the contact angle corresponding to the three-phase boundary point can be determined.
Fig. 3 is a schematic diagram of a full flow process for determining a contact angle according to an embodiment of the present application. As shown in fig. 3, for any three-phase boundary point, a circle may be defined by using the three-phase boundary point as a center and a preset distance as a radius, so as to determine a round contact angle statistical area, that is, a set area. The preset distance can be set according to actual requirements. Further, the pixel area of the set area in the oil-water-solid distribution image, that is, the total pixel area of the set area may be obtained. And then, based on the difference of the oil-water-solid three-phase colors, acquiring the pixel area occupied by the water phase area in the set area, namely the water phase pixel area. And finally, determining the contact angle according to the ratio of the water phase pixel area to the total pixel area. Similarly, the contact angle of all contact angles in the oil-water-solid distribution image set of each detection period can be determined. Therefore, compared with the traditional method, the method for determining the contact angle through the pixel area of the preset area is more accurate, is favorable for accurately expressing the size and the number of the contact angle inside the rock, and further accurately reflects the change of the wettability of the rock surface in the displacement process.
In the embodiment of the application, the contact angle corresponding to any three-phase boundary point can satisfy the following formula:
wherein θ is the contact angle corresponding to the three-phase boundary point, S wet Is the area of the water phase pixel, S total Is the total pixel area.
Specifically, the contact angle of each three-phase boundary point is calculated by a sector area method by taking the three-phase boundary point as the circle center. Compared with the traditional method, the method for determining the contact angle through the pixel area of the preset area is more accurate, is favorable for accurately expressing the size and the number of the contact angle inside the rock, and further accurately reflects the change of the wettability of the rock surface in the displacement process.
In an embodiment of the present application, determining the wettability of the contact angle according to the preset condition may include:
when the contact angle is smaller than the first threshold value, judging that the wettability of the contact angle is oleophilic;
in the case where the contact angle is greater than or equal to the first threshold value and less than or equal to the second threshold value, determining that the wettability of the contact angle is neutral wetting;
when the contact angle is larger than the second threshold value, the wettability of the contact angle is determined to be hydrophilic.
In the embodiment of the present application, the preset condition refers to dividing wettability of the contact angle according to a range interval where the angle of the contact angle is located, and the wettability can be divided into three types of lipophilicity, neutral wetting and hydrophilicity. Specifically, in the case where the contact angle is greater than the first threshold value, the wettability of the contact angle is determined to be oleophilic; in the case where the contact angle is greater than or equal to the first threshold value and less than or equal to the second threshold value, determining that the wettability of the contact angle is neutral wetting; when the contact angle is larger than the second threshold value, the wettability of the contact angle is determined to be hydrophilic. For example, the wettability is lipophilic, the wettability is neutral when the contact angle is 75 ° to 105 °, and the wettability is hydrophilic when the contact angle is greater than 105 °. Therefore, the wettability of the contact angle is divided according to the size of the contact angle, so that data statistics is facilitated, and the wettability change condition of the rock core in the displacement process is further intuitively reflected.
In an embodiment of the present application, the method may further include:
acquiring a training data set and a verification data set;
training an initial three-phase boundary point identification model through a training data set to obtain a trained three-phase boundary point identification model;
and inputting the verification data set into the trained three-phase boundary point identification model to obtain the three-phase boundary point identification model.
In the embodiment of the application, in order to identify the three-phase boundary points in the oil-water-solid distribution image, a three-phase boundary point identification model can be constructed. Specifically, a training data set and a verification data set can be acquired first, and a data base is improved for the construction of the three-phase boundary point identification model. In one example, the training data set and the validation data set each contain data relating to a plurality of contact angles, the data relating to each contact angle including a first coordinate, a second coordinate, and a size of the contact angle; the first coordinate refers to the abscissa of the three-phase boundary point in the oil-water-solid distribution image, the second coordinate refers to the ordinate of the three-phase boundary point in the oil-water-solid distribution image, and the contact angle is the contact angle of the three-phase boundary point. In this way, the related data including the first coordinate, the second coordinate and the contact angle are used as a training data set and a verification data set for constructing the three-phase boundary point identification model, which is beneficial to improving the accuracy of the identification result of the three-phase boundary point identification model. In another example, the data of the training data set and the validation data set may be acquired by a technician manually and stored to the system to provide a data base.
In the embodiment of the application, the initial three-phase boundary point recognition model can be trained by using the training data set so as to obtain a trained three-phase boundary point recognition model. In one example, a convolutional neural network may be employed as the three-phase junction identification model. Further, the first coordinate in the verification data set is input into the trained three-phase boundary point identification model to obtain a corresponding ordinate, and the three-phase boundary point coordinate, of which the error between the calculated ordinate and the actual ordinate is greater than a preset threshold value and is closest to the preset threshold value, is selected as the three-phase boundary point, so that the construction of the three-phase boundary point identification model is completed. Therefore, the accuracy of three-phase junction point identification is improved, and the accuracy of monitoring the wettability change of the core is improved.
In an embodiment of the present application, the training data set and the verification data set each include data related to a plurality of contact angles, and the data related to each contact angle includes a first coordinate, a second coordinate, and a size of the contact angle.
Specifically, the training data set and the verification data set each contain relevant data of a plurality of contact angles, and the relevant data of each contact angle comprises a first coordinate, a second coordinate and the size of the contact angle; the first coordinate refers to the abscissa of the three-phase boundary point in the oil-water-solid distribution image, the second coordinate refers to the ordinate of the three-phase boundary point in the oil-water-solid distribution image, and the contact angle is the contact angle of the three-phase boundary point. In another example, the data of the training data set and the validation data set may be acquired by a technician manually and stored to the system to provide a data base. In this way, the related data including the first coordinate, the second coordinate and the contact angle are used as a training data set and a verification data set for constructing the three-phase boundary point identification model, which is beneficial to improving the accuracy of the identification result of the three-phase boundary point identification model.
In a specific embodiment of the present application, a displacement experiment of two typical displacement fluids, steam and carbon dioxide, in a core model is taken as an example, so as to monitor the wettability change process in the process of alternately displacing carbon dioxide and steam.
In order to simulate the carbon dioxide and steam alternate displacement process, a core displacement experimental device comprising a steam and carbon dioxide displacement system, a core model system and a displacement dynamic monitoring system is assembled. The steam and carbon dioxide displacement system mainly comprises: connecting the high-precision double-cylinder plunger pump with the intermediate container, and then connecting the intermediate container with the six-way valve; the six-way valve is sequentially connected with the intermediate container, the carbon dioxide gas cylinder, the gas flow control meter, the electronic pressure gauge, the emptying pipeline and the output port pipeline. The core model system mainly comprises: and (3) arranging a temperature-resistant pressure-resistant core holder with a core inside, arranging the core holder in an incubator, setting the temperature of the incubator to be 50 ℃, and connecting the tail of the core holder with a back pressure valve. The pressurizing connection port is connected with a high-precision single-cylinder plunger pump and is used for enabling the outlet end of the core to keep target stratum pressure (5 MPa). The outlet end of the core model is connected with a measuring cylinder for measuring the liquid amount of the produced liquid, so that the core model system is built; the displacement dynamic monitoring system has the functions of counting real-time injection pressure and yield data, wherein an injection end electronic pressure meter data line connected with the six-way valve is connected with a computer, the injection end pressure data is transmitted, an electronic scale is placed below an outlet end measuring cylinder, and the yield dynamic data is transmitted.
After the three experimental systems are assembled, all valves are closed, the single-cylinder plunger pump is used for pumping pressure target stratum pressure, a nitrogen cylinder is connected with an emptying pipeline, the emptying pipeline valve of the six-way valve is opened, the nitrogen cylinder is opened for air tightness detection of a displacement experimental device, and a displacement experiment is carried out after no leakage point is detected. Setting the temperature of the incubator as a target temperature before a displacement experiment, opening a water phase intermediate container valve of a six-way valve after the temperature in a core holder reaches the target temperature, starting a high-precision double-cylinder plunger pump, performing saturated water work at a flow rate of 0.25mL/min, calculating the liquid phase permeability of the core according to Darcy's law, calculating the effective porosity of the core by dividing the difference between the volume of injected water and the volume of produced water by the apparent volume of the core until the outlet end of a back pressure valve stably produces water, and finishing the saturated water stage. And closing a water phase middle container valve of the six-way valve, opening an oil phase middle container valve of the six-way valve, carrying out saturated water work at the flow rate of 0.1mL/min until the outlet end of the back pressure valve is stable in oil production, completing a saturated oil stage, calculating initial oil saturation according to the difference between the injected oil volume and the produced oil divided by the apparent volume of the core, and marking the difference between the effective porosity and the initial oil saturation as the initial water saturation, and completing the saturated oil stage. Closing all valves, and aging the core with saturated oil in an incubator set to the target temperature for more than 72 hours to complete the initial state construction of the core model.
After the initial core model is completed, the initial displacement stage is divided into three parts, wherein the first stage is a steam pre-injection stage, the temperature of injected steam is 200 ℃, and 45PV steam is injected in the first stage; the second stage is a carbon dioxide injection section, and carbon dioxide gas of 5PV under stratum conditions is injected in the second stage; the third stage is a steam post injection stage, and 50PV steam is injected in the third stage.
In the injection process, taking 25PV as a time interval, taking out a core in a core holder to detect permeability change, and acquiring a scanning image by using a CT computer scanning technology. The injection volume nodes are taken as scanning nodes (25 PV,50PV,75PV and 100 PV), and selecting the scanned image of the end face at the specific position as a main study object. And selecting the CT scanning image of the rock core by using AVIZO three-dimensional visualization processing software, and adopting methods such as surface rendering processing and the like to obtain an initial oil-water-solid distribution image.
Firstly, carrying out color correction on an initial oil-water-solid distribution image, and dividing all the image colors into three colors based on oil-water-solid distribution. And then edge detection is carried out, the position and distribution difference of the oil-water two phases on the rock wall surface are highlighted, and an oil-water solid distribution image is obtained. Secondly, a convolutional neural network is utilized to mainly carry out recognition of a contact angle starting point, namely a three-phase boundary point; inputting other untrained abscissas into a training model to obtain the calculated ordinates of the three-phase boundary points; and selecting the three-phase boundary point coordinate which has the error between the calculated ordinate and the actual ordinate larger than a preset threshold and is closest to the preset threshold as the three-phase boundary point. And finally, calculating the contact angle of the training model by using the three-phase boundary point as a circle center through a sector area method, and summarizing the sizes and wettability changes of all the wetting angles in the CT image, thereby reflecting the wettability changes in the dynamic development process of the heavy oil. Taking the injection time 25PV (initial vapor flooding phase) as an example, a contact angle statistical table was output, and water wetting, oil wetting, and neutral wetting were divided according to the ranges in table 1, and table 1 is a 25PV vapor flooding contact angle identification data table.
TABLE 1
Summarizing the contact angle data in the core model acquired at the four injection time nodes to obtain a table 2 so as to reflect the dynamic change of wettability in the process of alternately displacing carbon dioxide and steam, wherein the table 2 is a contact angle change data table of each monitoring period.
TABLE 2
From the table, the injected fluid is mainly steam in the stage from 25PV to 50PV, the carbon dioxide injection time is shorter, the contact angle number of the rock surface is slightly increased, and the wettability variation amplitude of the contact angle is smaller; in the stages from 50PV to 75PV, all injected fluid is steam, but the contact time of carbon dioxide remained in the pores and the rock surface is prolonged, the contact angle quantity is increased by 31.5% under the common influence of high temperature carried by the steam, the contact angle increasing amplitude is far higher than that in other stages, the hydrophilicity is also greatly enhanced, and the proportion of the oil-wet contact angle is reduced by nearly half; the injected fluid was all steam during the 75PV to 100PV period, the contact angle number was reduced, and it showed less wettability change.
Fig. 4 is a block diagram of an apparatus for monitoring wettability of a core according to an embodiment of the present application. As shown in fig. 4, an embodiment of the present application provides an apparatus for monitoring wettability of a core, which may include:
A memory 410 configured to store instructions; and
the processor 420 is configured to call instructions from the memory 410 and when executing the instructions, to implement the method for monitoring core wettability described above.
Specifically, in embodiments of the present application, the processor 420 may be configured to:
acquiring a set of oil-water-solid distribution images of a plurality of detection periods of the core, wherein the set of oil-water-solid distribution images of any detection period comprises a preset number of oil-water-solid distribution images;
for any detection period, determining a plurality of three-phase boundary points in the oil-water-solid distribution image through a three-phase boundary point identification model;
respectively determining a contact angle corresponding to each three-phase junction point;
determining wettability of the contact angle according to preset conditions;
determining wettability data corresponding to the oil-water-solid distribution image set;
outputting wettability data corresponding to the oil-water-solid distribution image set to determine wettability change conditions of the rock core;
wherein the wettability data comprises the total number of contact angles and the ratio of contact angles at different wettabilities.
Further, the processor 420 may be further configured to:
acquiring the oil-water-solid distribution image set of the core in a plurality of detection periods comprises:
Scanning the rock core according to a preset period in the process of injecting the displacement fluid so as to obtain a preset number of scanning images of a plurality of detection periods;
processing the scanned image to distinguish oil-water-solid three phases in the scanned image and obtain an initial oil-water-solid distribution image;
performing color correction treatment on the initial oil-water-solid distribution image to obtain a treated image, wherein oil-water-solid phases in the treated image are respectively distinguished by different color representations;
and performing edge detection on the processed image to obtain a set of oil-water-solid distribution images with a plurality of detection periods.
In the embodiment of the present application, the preset period is set according to the increasing volume of the injected displacement fluid, and the preset number of scanned images are scanned images of the end faces of different positions of the core respectively.
Further, the processor 420 may be further configured to:
determining the contact angle corresponding to each three-phase junction point comprises the following steps:
for any three-phase boundary point, acquiring the total pixel area of a set area corresponding to the any three-phase boundary point, wherein the set area is a circular area formed by taking the any three-phase boundary point as a circle center and taking a preset distance as a radius;
acquiring the water phase pixel area occupied by the water phase area in the set area;
And determining the contact angle corresponding to any three-phase junction point according to the water phase pixel area and the total pixel area.
In the embodiment of the application, the contact angle corresponding to any three-phase boundary point satisfies the following formula:
wherein θ is the contact angle corresponding to the three-phase boundary point, S wet Is the area of the water phase pixel, S total Is the total pixel area.
Further, the processor 420 may be further configured to:
determining wettability of the contact angle according to preset conditions includes:
when the contact angle is smaller than the first threshold value, judging that the wettability of the contact angle is oleophilic;
in the case where the contact angle is greater than or equal to the first threshold value and less than or equal to the second threshold value, determining that the wettability of the contact angle is neutral wetting;
when the contact angle is larger than the second threshold value, the wettability of the contact angle is determined to be hydrophilic.
Further, the processor 420 may be further configured to:
the method further comprises the steps of:
acquiring a training data set and a verification data set;
training an initial three-phase boundary point identification model through a training data set to obtain a trained three-phase boundary point identification model;
and inputting the verification data set into the trained three-phase boundary point identification model to obtain the three-phase boundary point identification model.
In an embodiment of the present application, the training data set and the verification data set each include data related to a plurality of contact angles, and the data related to each contact angle includes a first coordinate, a second coordinate, and a size of the contact angle.
According to the technical scheme, the oil-water-solid distribution image set of a plurality of detection periods of the rock core is obtained firstly, then for any detection period, a plurality of three-phase junctions in the oil-water-solid distribution image are determined through the three-phase junction identification model, the contact angle corresponding to each three-phase junction is respectively determined, the wettability of the contact angle is determined according to preset conditions, and finally wettability data corresponding to the oil-water-solid distribution image set are output to determine the wettability change condition of the rock core, wherein the wettability data comprise the total number of the contact angles and the ratio of the contact angles under different wettabilities. The rock core wettability monitoring method and device can be suitable for monitoring rock core wettability changes in the displacement process under different development technologies, and output shows rock surface wettability changes under different development modes, so that the application range is wide, and the efficiency and accuracy of contact angle identification are improved.
Embodiments of the present application also provide a machine-readable storage medium having instructions stored thereon for causing a machine to perform the above-described method for monitoring core wettability.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In one typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include volatile memory in a computer-readable medium, random Access Memory (RAM) and/or nonvolatile memory, etc., such as Read Only Memory (ROM) or flash RAM. Memory is an example of a computer-readable medium.
Computer readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of storage media for a computer include, but are not limited to, phase change memory (PRAM), static Random Access Memory (SRAM), dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), read Only Memory (ROM), electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape disk storage or other magnetic storage devices, or any other non-transmission medium, which can be used to store information that can be accessed by a computing device. Computer-readable media, as defined herein, does not include transitory computer-readable media (transmission media), such as modulated data signals and carrier waves.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article or apparatus that comprises an element.
The foregoing is merely exemplary of the present application and is not intended to limit the present application. Various modifications and changes may be made to the present application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc. which are within the spirit and principles of the present application are intended to be included within the scope of the claims of the present application.
Claims (10)
1. A method for monitoring wettability of a core, comprising:
acquiring a set of oil-water-solid distribution images of a plurality of detection periods of the core, wherein the set of oil-water-solid distribution images of any detection period comprises a preset number of oil-water-solid distribution images;
for any detection period, determining a plurality of three-phase boundary points in the oil-water-solid distribution image through a three-phase boundary point identification model;
respectively determining a contact angle corresponding to each three-phase junction point;
determining wettability of the contact angle according to preset conditions;
determining wettability data corresponding to the oil-water-solid distribution image set;
outputting wettability data corresponding to the oil-water-solid distribution image set to determine wettability change conditions of the core;
wherein the wettability data includes a total number of contact angles and a ratio of contact angles at different wettabilities.
2. The method of claim 1, wherein acquiring a set of oil-water-solids distribution images of a plurality of detection cycles of a core comprises:
scanning the core according to a preset period in the process of injecting the displacement fluid so as to obtain a preset number of scanning images of the detection periods;
processing the scanned image to distinguish oil-water-solid three phases in the scanned image and obtain an initial oil-water-solid distribution image;
performing color correction processing on the initial oil-water-solid distribution image to obtain a processed image, wherein the oil-water-solid phases in the processed image are respectively represented and distinguished by different colors;
and performing edge detection on the processed image to obtain a set of oil-water-solid distribution images of the plurality of detection periods.
3. The method of claim 2, the preset period being set according to an increasing volume of the displacement fluid injected, the preset number of scan images being scan images of different position end faces of the core, respectively.
4. The method of claim 1, wherein the separately determining contact angles for each three-phase junction comprises:
For any three-phase boundary point, acquiring the total pixel area of a set area corresponding to the any three-phase boundary point, wherein the set area is a circular area formed by taking the any three-phase boundary point as a circle center and taking a preset distance as a radius;
acquiring the water phase pixel area occupied by the water phase area in the set area;
and determining the contact angle corresponding to the arbitrary three-phase junction point according to the water phase pixel area and the total pixel area.
5. The method of claim 4, wherein the contact angle corresponding to any three-phase junction satisfies the following equation:
wherein θ is the contact angle corresponding to the three-phase boundary point, S wet For the aqueous phase pixel area S total Is the total pixel area.
6. The method of claim 1, wherein the determining the wettability of the contact angle according to a preset condition comprises:
determining that wettability of the contact angle is oleophilic when the contact angle is less than a first threshold;
determining that the wettability of the contact angle is neutral wetting when the contact angle is greater than or equal to the first threshold value and less than or equal to a second threshold value;
and when the contact angle is greater than the second threshold value, determining that the wettability of the contact angle is hydrophilic.
7. The method according to claim 1, wherein the method further comprises:
acquiring a training data set and a verification data set;
training an initial three-phase boundary point recognition model through the training data set to reach the trained three-phase boundary point recognition model;
and inputting the verification data set into the trained three-phase boundary point identification model to obtain the three-phase boundary point identification model.
8. The method of claim 7, wherein the training data set and the validation data set each comprise data relating to a plurality of contact angles, the data relating to each contact angle comprising a first coordinate, a second coordinate, and a magnitude of the contact angle.
9. An apparatus for monitoring wettability of a core, comprising:
a memory configured to store instructions; and
a processor configured to invoke the instructions from the memory and when executing the instructions is capable of implementing the method for monitoring core wettability according to any one of claims 1 to 8.
10. A machine-readable storage medium having instructions stored thereon for causing a machine to perform the method for monitoring core wettability according to any one of claims 1 to 8.
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| CN117030706B (en) * | 2023-08-09 | 2024-03-19 | 大庆亿莱检验检测技术服务有限公司 | Detection method for adsorption of nano oil displacement agent |
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