Thermal recovery simulation experiment device and method for oil sands and extra-heavy oil reservoirs

Abstract

A thermal recovery simulation experiment device and method for oil sands and extra-heavy oil reservoirs, relating to the technical field of oil sands and extra-heavy oil development. The experiment device comprises: a three-dimensional geological simulation model (1), which comprises a model housing (11) having a cavity, wherein the model housing is configured to be filled with sand, and the model housing has a vacuum pump interface (12) and a recovery interface (13); and at least two vertical simulation wells (14), one horizontal steam-injection simulation well (15) and one horizontal production simulation well (16) that can be arranged in the housing, wherein a first on-off valve (17) and a first connector (18) located outside the model housing are connected in sequence to the end of each vertical simulation well, a second on-off valve (19) and a second connector (110) located outside the model housing are connected in sequence to the end of the horizontal steam-injection simulation well, etc. For oil sands and extra-heavy oil reservoirs, the present application can visually demonstrate influences and development patterns under different thermal recovery modes at high temperature and high pressure.

Description

Experimental apparatus and method for thermal recovery simulation of oil sands and extra-heavy oil reservoirs

[0001] Related applications

[0002] This application claims priority to Chinese Patent Application No. 202411629528.5, filed on November 14, 2024, and incorporates the entire contents of the disclosure of the aforementioned patent application as part of this application. Technical Field

[0003] This application relates to the field of oil sands and extra-heavy oil development technology, and in particular to an experimental apparatus and method for simulating thermal recovery of oil sands and extra-heavy oil reservoirs. Background Technology

[0004] Oil sands and extra-heavy oil are important petroleum resources widely distributed worldwide. The Athabasca oil sands region in Canada and the Orinoco heavy oil belt in Venezuela are two of the world's largest unconventional heavy oil-rich areas (geological reserves of approximately 220 billion tons and 180 billion tons, respectively). The geological reserves of extra-heavy oil and oil sands projects in these two regions are enormous. Oil sands and extra-heavy oil differ significantly from heavy oil reservoirs in China, and current mature heavy oil development technologies and experience are not fully adapted to their economically effective development and enhanced oil recovery. Compared to heavy oil in China, Venezuelan extra-heavy oil and Canadian oil sands are distributed on a large scale and have relatively good reservoir properties; the crude oil has low density, high asphaltene and sulfur content, high heavy metal content, and low gum content. In particular, Venezuelan extra-heavy oil exhibits a certain degree of fluidity under formation conditions.

[0005] Current SAGD development technology for Canadian oil sands is costly, posing significant challenges to improving SAGD development efficiency, developing new oil sands development technologies, and optimizing SAGD development design under complex geological reservoir conditions. Traditional SAGD development technology for oil sands is energy-intensive, and research and field implementation of new technologies to improve SAGD development efficiency are currently in their early stages. In comparable Canadian blocks, peak stable production of SAGD wells is 350-520 barrels per day, with an oil-steam ratio of 0.2-0.4, and horizontal well utilization is generally 60-70%. Research is insufficient on methods for evaluating and predicting high-quality oil sands reservoirs under complex geological reservoir conditions, methods for predicting SAGD development indicators, and SAGD development strategies in situations with gas caps / top-bottom water / interlayers.

[0006] Following the sustained cold extraction and development of Venezuelan super-heavy oil, further enhancing recovery rates and developing new replacement technologies presents significant challenges. Existing projects in the heavy oil belt currently employ horizontal wells for natural energy cold extraction, resulting in low primary recovery rates (approximately 5%-12%), with only a few incomplete pilot tests of thermal recovery. Replacement development technologies after cold extraction of super-heavy oil are currently in the exploratory stage, lacking commercially successful precedents for reference. The limited results of the few incomplete pilot tests conducted in the heavy oil belt, such as horizontal well steam injection and vertical well steam drive, are not particularly relevant.

[0007] Furthermore, as important energy assets, the quantitative prediction of recoverable reserves and asset valuation of Canadian oil sands and Venezuelan extra-heavy oil are crucial. It is necessary to develop technologies for oil sands and extra-heavy oil reservoirs that can study their development patterns, influencing factors, and quantitatively predict recoverable reserves. Summary of the Invention

[0008] The applicant discovered that current simulation experimental devices are designed for heavy oil. For example, the invention patent with publication number CN115749708A discloses a simulation device and method for establishing connectivity between vertical and horizontal wells in heavy oil. This device can be used for large-scale three-dimensional physical simulation of hydraulic micro-fracture and VHSD vertical-horizontal well group development of ultra-heavy oil reservoirs. It facilitates the intuitive understanding of the expansion law of the micro-fracture zone in hydraulic micro-fracture oil sand reservoir operations, reveals the micro-fracture stimulation mechanism, optimizes construction parameters, and is more conducive to analyzing the principles of VHSD vertical-horizontal well connectivity, increasing initial recovery rate, and overcoming reservoir heterogeneity. It provides theoretical guidance and technical support for improving the hydraulic connectivity mechanism and parameter optimization of VHSD vertical-horizontal wells and rapidly establishing a uniform connectivity zone between VHSD wells. For example, invention patent CN116856889A discloses a heavy oil fire-flooding horizontal section experimental device and its usage method. Through the design of the connecting structure and sealing components, it achieves the collection and isolation of heavy oil during fire-flooding experiments, avoiding damage to the horizontal section. Simultaneously, by rotating the handle and moving the threaded pipe, the position of the sealing components can be adjusted to isolate the heavy oil and high-temperature gas. This mainly solves the problem of improving the sampling rate and applicability of heavy oil in fire-flooding experiments, while also addressing the issue of fire lines easily spreading to the horizontal section of the three-dimensional well network, thus providing more reliable experimental guidance and adjustment measures. For another example, invention patent CN115704291A discloses a heavy oil reservoir multi-element thermal composite oil displacement experimental device, system, and method. This experimental device can conduct steam flooding, chemical flooding, or multiple oil displacement systems independently, and can also generate multi-element composite oil displacement systems based on multiple oil displacement systems. Simultaneously, the experimental device can also heat the oil displacement system and ensure its injection temperature. In addition, the experimental apparatus can inject different oil displacement systems sequentially in a slug injection manner as needed, and is compatible with conventional slug injection to meet more experimental requirements.

[0009] The aforementioned simulation devices and methods are designed for conventional heavy oil reservoirs and cannot accurately simulate reservoir geological features such as reservoir water and heterogeneity. Furthermore, they cannot simulate conditions under different thermal recovery methods and cannot accurately monitor saturation, temperature field, and pressure field data in real time during the experiment.

[0010] In order to overcome the above-mentioned defects of the prior art, the technical problem to be solved by the embodiments of this application is to provide a thermal recovery simulation experimental device and method for oil sands and ultra-heavy oil reservoirs, which can intuitively show the impact and development law of different thermal recovery methods under high temperature and high pressure conditions for oil sands and ultra-heavy oil reservoirs.

[0011] The specific technical solution of this application embodiment is as follows:

[0012] This application provides a simulation experimental device for thermal recovery of oil sands and ultra-heavy oil reservoirs, which includes a three-dimensional geological simulation model, an injection unit, and a recovery unit.

[0013] The three-dimensional geological simulation model includes a model shell with a cavity, the interior of which is filled with sand. The model shell has a vacuum pump interface and a recovery interface. The three-dimensional geological simulation model also includes at least two vertical simulation wells, one steam injection horizontal simulation well, and one production horizontal simulation well that can be installed within the shell. Each vertical simulation well is sequentially connected to a first on / off valve and a first connector located outside the model shell at its end. The steam injection horizontal simulation well is sequentially connected to a second on / off valve and a second connector located outside the model shell at its end. The production horizontal simulation well is sequentially connected to a third on / off valve and a third connector located outside the model shell at its end. The three-dimensional geological simulation model also includes a vacuum pump connected to the vacuum pump interface via a fourth on / off valve, a first pipeline connected to the recovery interface, and a first heating unit for heating the model shell. The first pipeline is equipped with a fifth on / off valve, a first back pressure valve, a first pressure gauge, and a first flow meter.

[0014] The injection unit includes a piston oil tank, a piston water tank, a second pipeline connected to the piston water tank, a pressurization unit, a third pipeline connected to the piston oil tank, a second heating unit for heating the piston water tank, and a third heating unit for heating the piston oil tank. The second pipeline is equipped with a second flow meter and a second pressure gauge, and can be connected to the first connector corresponding to one of the vertical simulated wells. The pressurization unit is used to pressurize the piston oil tank and the piston water tank. The third pipeline is equipped with a third flow meter and a third pressure gauge, and can be connected to the third connector.

[0015] The recovery unit includes a fourth pipeline and a first recovery container for collecting material discharged from the fourth pipeline. A second back pressure valve and a fourth pressure gauge are installed on the fourth pipeline, which is used to connect to the first connector corresponding to one of the vertical simulated wells.

[0016] Optionally, a fourth flow meter is installed on the fourth pipeline;

[0017] The injection unit includes: a steam generator that can be connected to the piston tank; a fifth pipeline connected to the steam generator, the fifth pipeline being equipped with a fifth flow meter and a pressure regulating valve; the fifth pipeline is used to connect to the first connector corresponding to one of the vertical simulated wells;

[0018] The simulated experimental setup for thermal recovery of oil sands and ultra-heavy oil reservoirs includes:

[0019] Multiple temperature and pressure probes are inserted at different positions inside the model housing.

[0020] Optionally, the oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a steam injection test state. In the steam injection test state, the fifth pipeline is first connected to the first joint corresponding to one of the vertical simulated wells, and the pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the vertical simulated well under the action of the pressurization unit. After the steam injection is completed, the fourth pipeline is then connected to the first joint corresponding to the vertical simulated well, and the second back pressure valve is adjusted to the test pressure to extract crude oil and record the crude oil extraction volume through the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

[0021] Optionally, the oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a steam drive test state. In the steam drive test state, the fifth pipeline is connected to the first joint corresponding to one of the vertical simulated wells, and the fourth pipeline is connected to the first joint corresponding to another vertical simulated well. The pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the vertical simulated well under the action of the pressurization unit. Crude oil is collected through the fourth pipeline and the other vertical simulated well, and the crude oil production is recorded by the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

[0022] Optionally, the oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a SAGD test state. In the SAGD test state, the fifth pipeline is connected to the second joint of the steam injection horizontal simulation well, and the fourth pipeline is connected to the third joint of the production horizontal simulation well. The pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the steam injection horizontal simulation well under the action of the pressurization unit. Crude oil is collected through the fourth pipeline and the production horizontal simulation well, and the crude oil production is recorded through the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

[0023] Optionally, the model housing has a first transparent window on its side wall, the position of which corresponds to the position of the steam injection level simulation well and the production level simulation well.

[0024] Optionally, the model housing has a second transparent window on its side wall, the position of which corresponds to the position of the vertical simulated well.

[0025] Optionally, the end of each of the vertical simulated wells is connected to the first on / off valve via a first quick-connect fitting;

[0026] The end of the steam injection horizontal simulation well is connected to the second on / off valve via a second quick-connect coupling;

[0027] The end of the production level simulation well is connected to the third on / off valve via a third quick-connect fitting.

[0028] Optionally, the second heating unit is also used to heat the steam generator, and the second heating unit is an air bath heating device.

[0029] This application also provides an experimental method using the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device as described above, including the following steps:

[0030] Reservoir geological construction: Sand is filled into the cavity of the model shell and interlayer material is arranged according to the interlayer situation of the reservoir to construct the reservoir geology;

[0031] Vacuuming: After the geological construction of the reservoir is completed, the cavity of the model shell is evacuated using a vacuum pump;

[0032] To obtain the porosity within the cavity: the first solution is filled into the piston tank, the second pipeline is connected to the first connector corresponding to one of the vertical simulated wells, the fourth pipeline is connected to the first connector corresponding to the other vertical simulated well, the second back pressure valve is controlled to the required test pressure, the pressurization unit is turned on to drive the first solution in the piston tank into the cavity of the model shell, and the porosity is calculated by the amount of the first solution filled and the volume of the cavity of the model shell.

[0033] To obtain the permeability within the cavity: During the process of obtaining the porosity within the cavity, the pressurization unit is activated to drive the first solution in the piston tank into the cavity of the model shell. The injection rate of the first solution is changed, and the pressure difference is obtained based on the pressure values ​​of the second and fourth pressure gauges. Then, the permeability within the cavity is obtained using Darcy's formula.

[0034] Obtaining saturation: After the cavity of the model shell is filled with the first solution, the third pipeline is connected to the third connector of the production horizontal simulation well, and the fourth pipeline is connected to the first connector corresponding to one of the vertical simulation wells. The second back pressure valve is controlled to the required test pressure, and the pressurization unit is turned on to drive the crude oil in the piston oil tank into the cavity of the model shell. The injection volume of crude oil is measured by the third flow meter. When the crude oil and the first solution flow steadily into the first recovery container, the pressurization unit is turned off. The saturation of the first solution and the crude oil in the cavity of the model shell are obtained according to the crude oil and the first solution in the first recovery container, the injection volume of crude oil and the filling volume of the first solution.

[0035] Optionally, a fourth flow meter is installed on the fourth pipeline;

[0036] The injection unit includes: a steam generator that can be connected to the piston tank; a fifth pipeline connected to the steam generator, the fifth pipeline being equipped with a fifth flow meter and a pressure regulating valve; the fifth pipeline is used to connect to the first connector corresponding to one of the vertical simulated wells;

[0037] Multiple temperature and pressure probes are inserted at different positions inside the model housing.

[0038] Optionally, the experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device further includes the following steps:

[0039] Steam injection test: First, connect the fifth pipeline to the first connector corresponding to one of the vertical simulated wells, adjust the pressure regulating valve to the required test pressure, and turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the vertical simulated well; after the steam injection is completed, connect the fourth pipeline to the first connector corresponding to the vertical simulated well, adjust the second back pressure valve to the test pressure, connect the fourth pipeline to the vertical simulated well to extract crude oil from the cavity, and record the crude oil extraction amount through the fourth flow meter to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

[0040] Optionally, the experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device further includes the following steps:

[0041] Steam drive test: Connect the fifth pipeline to the first connector corresponding to one of the vertical simulated wells, and connect the fourth pipeline to the first connector corresponding to the other vertical simulated well. Adjust the pressure regulating valve to the required test pressure, and turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the vertical simulated well. Collect crude oil through the fourth pipeline and the other vertical simulated well, and record the crude oil output through the fourth flow meter to obtain the remaining crude oil reserves. Collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

[0042] Optionally, the experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device further includes the following steps:

[0043] SAGD Test: Connect the fifth pipeline to the second joint of the steam injection horizontal simulation well, and connect the fourth pipeline to the third joint of the production horizontal simulation well; adjust the pressure regulating valve to the required test pressure, turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the steam injection horizontal simulation well, collect crude oil through the fourth pipeline and the production horizontal simulation well, and record the crude oil output through the fourth flow meter to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

[0044] The technical solution of this application embodiment has the following significant beneficial effects:

[0045] The oil sands and extra-heavy oil reservoir thermal recovery simulation experimental apparatus and method described in this application can construct different oil sands and extra-heavy oil reservoirs and obtain parameters such as porosity, permeability, and saturation of the constructed reservoir geology. These parameters are then used to simulate the conditions under different thermal recovery methods under high temperature and high pressure. Knowing the corresponding porosity, permeability, and saturation parameters, the oil sands and extra-heavy oil reservoir thermal recovery simulation experimental apparatus can simulate different gas injection methods such as steam huff and puff, steam drive, and SAGD, and finally obtain the remaining crude oil reserves.

[0046] Specific embodiments of this application are disclosed in detail with reference to the following description and accompanying drawings, indicating how the principles of this application can be adopted. It should be understood that the embodiments of this application are not limited in scope. Features described and / or shown for one embodiment may be used in the same or similar manner in one or more other embodiments, combined with features in other embodiments, or substituted for features in other embodiments. Attached Figure Description

[0047] The accompanying drawings described herein are for illustrative purposes only and are not intended to limit the scope of this application in any way. Furthermore, the shapes and scales of the components in the drawings are merely illustrative to aid in understanding this application and do not specifically limit the shapes and scales of the components. Those skilled in the art, guided by the teachings of this application, can select various possible shapes and scales to implement this application according to specific circumstances.

[0048] Figure 1 is a schematic diagram of the structure of the thermal recovery simulation experimental device for oil sands and ultra-heavy oil reservoirs in the embodiments of this application;

[0049] Figure 2 is a schematic diagram of the structure of the three-dimensional geological simulation model in the embodiment of this application;

[0050] Figure 3 is a schematic diagram of the steam injection test of the thermal recovery simulation experimental device for oil sands and super-heavy oil reservoirs in the embodiments of this application.

[0051] Figure 4 is a schematic diagram of the steam drive test (single-well steam injection and single-well oil production) of the thermal recovery simulation experimental device for oil sands and super-heavy oil reservoirs in the embodiments of this application;

[0052] Figure 5 is a schematic diagram of the steam drive test (single-well steam injection and multi-well oil production) of the thermal recovery simulation experimental device for oil sands and super-heavy oil reservoirs in the embodiments of this application;

[0053] Figure 6 is a schematic diagram of the structure of the vertical well steam injection horizontal well oil production / horizontal well steam injection vertical well oil production of the thermal recovery simulation experimental device for oil sands and super heavy oil reservoirs in the embodiments of this application.

[0054] Figure 7 is a schematic diagram of the SAGD test of the thermal recovery simulation experimental device for oil sands and super-heavy oil reservoirs in the embodiments of this application.

[0055] The reference numerals in the above figures are as follows: 1. Three-dimensional geological simulation model; 11. Model shell; 12. Vacuum pump interface; 13. Recovery interface; 14. Vertical simulation well; 15. Steam injection horizontal simulation well; 16. Production horizontal simulation well; 17. First on / off valve; 18. First connector; 19. Second on / off valve; 110. Second connector; 111. Third on / off valve; 112. Third connector; 113. Fourth on / off valve; 114. Vacuum pump; 115. First pipeline; 116. Fifth on / off valve; 117. First back pressure valve; 118. First pressure gauge; 119. First flow meter; 120. First heating unit; 121. First transparent window; 122. Second transparent window; 123. First quick connector; 124. Second quick connector; 125. Third quick connector; 126. Second recovery container; 127. Sand filling port; 128. Opening; 129. Computer; 130. Twelfth shut-off valve; 131. Drain line; 2. Injection unit; 21. Piston oil tank; 22. Piston water tank; 23. Second pipeline; 24. Second flow meter; 25. Second pressure gauge; 26. Pressurization unit; 27. Third pipeline; 28. Third flow meter; 29. ​​Third pressure gauge; 210. Second heating unit; 211. Third heating unit; 212. Steam generator; 213. Fifth pipeline; 214. Fifth flow meter; 215. Pressure regulating valve; 216. Sixth shut-off valve; 217. Seventh shut-off valve; 218. Third recovery container; 219. Eighth shut-off valve; 220. Fourth connector; 221. Ninth shut-off valve; 222. Fifth connector; 223. Seventh connector; 224. Eleventh shut-off valve; 3. Harvesting unit; 31. Fourth pipeline; 32. Second back pressure valve; 33. Fourth pressure gauge; 34. First recovery container; 35. Fourth flow meter; 36. Sand filter; 37. Sixth connector; 38. Tenth shut-off valve; 4. Temperature probe; 5. Pressure probe. Detailed Implementation

[0056] The details of this application can be more clearly understood by referring to the accompanying drawings and the description of specific embodiments. However, the specific embodiments of this application described herein are only for explaining the purpose of this application and should not be construed as limiting this application in any way. Under the teachings of this application, those skilled in the art can conceive of any possible modifications based on this application, and these should all be considered to fall within the scope of this application. It should be noted that when an element is referred to as being "set on" another element, it can be directly on the other element or there may be an intervening element. When an element is referred to as being "connected" to another element, it can be directly connected to the other element or there may be an intervening element. The terms "mounted," "connected," and "connected" should be interpreted broadly, for example, they can refer to mechanical or electrical connections, or internal communication between two elements, and can be direct connections or indirect connections through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms according to the specific circumstances. The terms "vertical," "horizontal," "upper," "lower," "left," "right," and similar expressions used herein are for illustrative purposes only and do not represent the only embodiments.

[0057] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the application. The term "and / or" as used herein includes any and all combinations of one or more of the associated listed items.

[0058] To visually demonstrate the impact and development patterns of different thermal recovery methods under high temperature and high pressure conditions in oil sands and extra-heavy oil reservoirs, this application proposes a thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs. Figure 1 is a schematic diagram of the structure of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs in an embodiment of this application. As shown in Figure 1, the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs may include:

[0059] A three-dimensional geological simulation model 1 includes: a model shell 11 with a cavity, the model shell 11 being filled with sand, and the model shell 11 having a vacuum pump interface 12 and a recovery interface 13; at least two vertical simulation wells 14, one steam injection horizontal simulation well 15, and one production horizontal simulation well 16 that can be installed inside the shell; each vertical simulation well 14 is sequentially connected to a first on / off valve 17 and a first connector 18 located outside the model shell 11 at its end; the steam injection horizontal simulation well 15 is sequentially connected to a first on / off valve 17 and a first connector 18 located outside the model shell 11 at its end. The second shut-off valve 19 and the second connector 110; the end of the production horizontal simulation well 16 is sequentially connected to the third shut-off valve 111 and the third connector 112 located outside the model shell 11; the vacuum pump 114 is connected to the vacuum pump interface 12 through the fourth shut-off valve 113; the first pipeline 115 is connected to the recovery interface 13, and the first pipeline 115 is equipped with the fifth shut-off valve 116, the first back pressure valve 117, the first pressure gauge 118, and the first flow meter 119; the first heating unit 120 is used to heat the model shell 11;

[0060] Injection unit 2 includes: a piston oil tank 21; a piston water tank 22; a second pipeline 23 connected to the piston water tank 22, the second pipeline 23 being equipped with a second flow meter 24 and a second pressure gauge 25, and the second pipeline 23 being able to connect to a first connector 18 corresponding to one of the vertical simulated wells 14; a pressurization unit 26 for pressurizing the piston oil tank 21 and the piston water tank 22; a third pipeline 27 connected to the piston oil tank 21, the third pipeline 27 being equipped with a third flow meter 28 and a third pressure gauge 29, and the third pipeline 27 being able to connect to a third connector 112; a second heating unit 210 for heating the piston water tank 22; and a third heating unit 211 for heating the piston oil tank 21.

[0061] The recovery unit 3 includes: a fourth pipeline 31, on which a second back pressure valve 32 and a fourth pressure gauge 33 are installed; the fourth pipeline 31 is used to connect to a first connector 18 corresponding to one of the vertical simulated wells 14; and a first recovery container 34 for collecting the material discharged from the fourth pipeline 31.

[0062] Figure 2 is a schematic diagram of the structure of the three-dimensional geological simulation model in this embodiment. As shown in Figure 2, the top of the model shell 11 can be provided with multiple sand filling ports 127. Sealing elements are provided at the sand filling ports 127 for sealing the ports 127. The sealing elements and the sand filling ports 127 can be detachably installed. The sand filling ports 127 are used to fill sand into the cavity of the model shell 11. For example, sand of different densities can be filled. Depending on the interlayer conditions of the simulated oil reservoir, interlayer materials such as sandstone and mudstone can be arranged to simulate different oil layer development characteristics, reservoir properties, and heterogeneity. The multiple sand filling ports 127 can extend along the horizontal extension direction of the model shell 11 to facilitate sand filling at various locations within the model shell 11. An opening 128 is provided on the lower side of the model shell 11. A sealing element is also provided at this opening 128 for sealing. The sealing element and the opening 128 can be detachably installed. The opening 128 can be used to drain materials such as sand from the model housing 11 for subsequent experiments. For example, the aforementioned seals can all be in the form of flanges. Furthermore, a vertical simulated well 14 is provided between each pair of adjacent sand-filling openings 127. The bottom of the model housing 11 can be connected to a drain line 131 with a twelfth on / off valve 130.

[0063] As a feasible solution, the sidewall of the model shell 11 may have a first transparent window 121, the position of which corresponds to the positions of the steam injection horizontal simulation well 15 and the production horizontal simulation well 16. The sidewall of the model shell 11 may also have a second transparent window 122, the position of which corresponds to the position of the vertical simulation well 14. Through the transparent windows, the development of the steam chamber and the fluid flow state within the cavity of the model shell 11 during the experiment can be observed.

[0064] On the first pipeline 115, the first pressure gauge 118 is generally located upstream of the first back pressure valve 117 to accurately detect the pressure at the recovery port 13 of the model housing 11. A second recovery container 126 may be provided at the end of the first pipeline 115.

[0065] As a feasible solution, the first heating unit 120 can heat the model shell 11 using a liquid bath. The model shell 11 can have a sandwich structure, and the first heating unit 120 of the liquid bath is connected to the sandwich structure through two pipelines, forming a circulation channel. The liquid bath heating method makes the heating of the model shell 11 more uniform, and the relative temperature deviation of the sand at different locations within the model shell 11 is smaller, which is beneficial to improving the accuracy of the experiment. The first heating unit 120 can be used to simulate the condition of an oil reservoir at a certain temperature in the oil sand and ultra-heavy oil reservoir thermal recovery simulation experimental device.

[0066] As a feasible solution, a steam injection horizontal simulation well 15 and a production horizontal simulation well 16 are located below at least two vertical simulation wells 14, thus reducing mutual interference. Generally, a steam injection horizontal simulation well 15 is located above the production horizontal simulation well 16, and the two are set substantially parallel to each other.

[0067] As a feasible solution, the end of each vertical simulation well 14 is connected to the first on / off valve 17 via a first quick-connect coupling 123. The end of the steam injection horizontal simulation well 15 is connected to the second on / off valve 19 via a second quick-connect coupling 124. The end of the production horizontal simulation well 16 is connected to the third on / off valve 111 via a third quick-connect coupling 125. The first quick-connect coupling 123, the second quick-connect coupling 124, and the third quick-connect coupling 125 can each include a male quick-connect coupling and a female quick-connect coupling. This structure allows for quick connection and disassembly under different test conditions. When not in use, excess simulation wells can be disassembled to avoid affecting fluid flow.

[0068] As a feasible solution, the thermal recovery simulation experimental device for oil sands and ultra-heavy oil reservoirs includes multiple temperature probes 4 and pressure probes 5 inserted at different positions within the model shell 11. This structure allows for precise monitoring of temperature and pressure changes in the reservoir at different times and locations. The temperature probes 4 and 5 can be thermo-pressure probes, allowing the same probe to monitor both temperature and pressure. The temperature probes 4 and 5 can be connected to a computer 129 for data acquisition and recording.

[0069] The outlet of the pressurization unit 26 can be connected to the inlet of the piston tank 22 via the sixth shut-off valve 216. The outlet of the pressurization unit 26 can be connected to the inlet of the piston oil tank 21 via the seventh shut-off valve 217. The inlet of the pressurization unit 26 can be connected to the third recovery container 218. Alternatively, to ensure that the pressurization pressure meets the requirements, the pressurization unit 26 can be a plunger pump. The piston tank 22 is used to contain a first solution, which can be output from the second pipeline 23 under the action of the pressurization unit 26. The first solution can be a relatively stable substance that does not readily react with the crude oil or the substances filled in the model shell 11, such as a sodium chloride solution. The piston oil tank 21 is used to contain crude oil, which can be output from the third pipeline 27 under the action of the pressurization unit 26.

[0070] The end of the second pipeline 23 can be connected in sequence to the eighth shut-off valve 219 and the fourth connector 220. The end of the third pipeline 27 can be connected in sequence to the ninth shut-off valve 221 and the fifth connector 222.

[0071] As a feasible solution, the second heating unit 210 can heat the piston water tank 22 using an air bath. The third heating unit 211 can heat the piston oil tank 21 using a liquid bath. Therefore, the piston oil tank 21 is placed inside the piston oil tank 21 jacket, with a gap between them. The third heating unit 211 is connected to the gap through two pipelines, and the four form a circulation channel. The liquid bath heating method makes the piston oil tank 21 heated more evenly.

[0072] On the fourth pipeline 31, the fourth pressure gauge 33 is located upstream of the second back pressure valve 32, enabling the fourth pressure gauge 33 to measure the pressure at the corresponding connection point of the fourth pipeline 31. Alternatively, a fourth flow meter 35 may be installed on the fourth pipeline 31. Upstream of the fourth pipeline 31, for example upstream of the fourth flow meter 35, a sand filter 36 may be connected. The upstream end of the fourth pipeline 31 may be sequentially connected to a tenth shut-off valve 38 and a sixth connector 37. Alternatively, the pipeline may be divided into multiple branches upstream of the fourth flow meter 35, each branch equipped with a tenth shut-off valve 38 and a sixth connector 37, allowing the fourth pipeline 31 to simultaneously connect to the first connectors 18 corresponding to multiple vertical simulated wells 14.

[0073] A fourth flow meter 35 can be installed on the fourth pipeline 31 to monitor the flow rate through the fourth pipeline 31. The injection unit 2 may include: a steam generator 212, which can be connected to the piston tank 22; a fifth pipeline 213 connected to the steam generator 212, on which a fifth flow meter 214 and a pressure regulating valve 215 are installed; the fifth pipeline 213 is used to connect to the first connector 18 corresponding to one of the vertical simulated wells 14. A seventh connector 223 is connected to the end of the fifth pipeline 213. An eleventh on / off valve 224 is connected between the steam generator 212 and the piston tank 22 to achieve on / off switching. There can be multiple fifth pipelines 213, and all of them are connected to the steam generator 212. According to experimental needs, multiple fifth pipelines 213 can be connected to the first connectors 18 corresponding to multiple vertical simulated wells 14 respectively to achieve the purpose of multi-well gas injection. The second heating unit 210 can also heat the steam generator 212, for example, by using an air bath to heat the steam generator 212 so that the steam generator 212 is at a suitable ambient temperature.

[0074] The thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs can be equipped with a steam injection test mode. Figure 3 is a schematic diagram of the steam injection test mode of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs in this embodiment of the application. As shown in Figure 3, in the steam injection test mode, the fifth pipeline 213 is first connected to the first connector 18 corresponding to one of the vertical simulated wells 14, and the pressure regulating valve 215 is adjusted to the required test pressure, so that the steam generated by the steam generator 212 is injected into the cavity of the model shell 11 through the vertical simulated well 14 under the action of the pressurization unit 26. After the steam injection is completed, the fourth pipeline 31 is then connected to the first connector 18 corresponding to the vertical simulated well 14, and the second back pressure valve 32 is adjusted to the test pressure to extract crude oil and record the crude oil extraction amount through the fourth flow meter 35; the temperature probe 4 and the pressure probe 5 are used to collect the temperature and pressure changes during the experiment.

[0075] Connect one vertical simulated well 14 for the experiment to the first on / off valve 17 via the first quick connector 123. Do not install other unused simulated wells into the model housing 11. Connect the sixth connector 37 at the end of the fifth pipeline 213 to the first connector 18 corresponding to the vertical simulated well 14. Adjust the pressure regulating valve 215 to the required test pressure, ensuring the fifth pipeline 213 is connected to the pipeline corresponding to the vertical simulated well 14. This allows steam generated by the steam generator 212 to be injected into the cavity of the model housing 11 through the vertical simulated well 14 via the pressurization unit 26. Specifically, the pressurization unit 26 forces the first solution in the piston tank 22 into the steam generator 212, and the steam generated by the steam generator 212 is injected into the cavity of the model housing 11. After steam injection is complete, connect the fourth pipeline 31 to the first connector 18 corresponding to the vertical simulated well 14. Adjust the second back pressure valve 32 to the test pressure to extract crude oil and record the crude oil extraction rate via the fourth flow meter 35.

[0076] The thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs can be equipped with a steam drive test state. Figure 4 is a structural schematic diagram of the steam drive test (single-well steam injection and single-well oil production) of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs in this embodiment of the application, and Figure 5 is a structural schematic diagram of the steam drive test (single-well steam injection and multi-well oil production) of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs in this embodiment of the application. As shown in Figures 4 and 5, in the steam drive test state, the fifth pipeline 213 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14, and the fourth pipeline 31 is connected to the first connector 18 corresponding to another vertical simulated well 14. The pressure regulating valve 215 is adjusted to the required test pressure, so that the steam generated by the steam generator 212 is injected into the cavity of the model shell 11 through the vertical simulated well 14 under the action of the pressurization unit 26. Crude oil is collected through the fourth pipeline 31 and the other vertical simulated well 14, and the crude oil production is recorded by the fourth flow meter 35. The temperature probe 4 and the pressure probe 5 are used to collect the temperature and pressure changes during the experiment. Under steam drive test conditions, oil production can be carried out by injecting gas into a single well, or by injecting gas into multiple wells.

[0077] In other feasible steam drive test conditions, Figure 6 is a schematic diagram of the vertical well steam injection horizontal well production / horizontal well steam injection vertical well production structure of the thermal recovery simulation experimental device for oil sands and super-heavy oil reservoirs in this application embodiment. As shown in Figure 6, the fifth pipeline 213 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14, and the fourth pipeline 31 is connected to the third connector 112 corresponding to the production horizontal simulated well 16. Other states are similar to those described above. Alternatively, the fifth pipeline 213 is connected to the second connector 110 corresponding to the steam injection horizontal simulated well 15, and the fourth pipeline 31 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14. Other states are similar to those described above.

[0078] The thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs can be in a SAGD test state. Figure 7 is a schematic diagram of the SAGD test structure of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs in this embodiment of the application. As shown in Figure 7, in the SAGD test state, the fifth pipeline 213 is connected to the second joint 110 of the steam injection horizontal simulation well 15, and the fourth pipeline 31 is connected to the third joint 112 of the production horizontal simulation well 16. The pressure regulating valve 215 is adjusted to the required test pressure, so that the steam generated by the steam generator 212 is injected into the cavity of the model shell 11 through the steam injection horizontal simulation well 15 under the action of the pressurization unit 26. Crude oil is collected through the fourth pipeline 31 and the production horizontal simulation well 16, and the crude oil production is recorded through the fourth flow meter 35. The temperature probe 4 and the pressure probe 5 are used to collect the temperature and pressure changes during the experiment.

[0079] In all of the above embodiments, the piston oil tank 21 may be filled with extra-heavy oil.

[0080] This application also proposes an experimental method using the above-mentioned oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device, which may include the following steps:

[0081] Reservoir geology construction: Sand is filled into the cavity of the model shell 11 and interlayer materials are arranged according to the interlayer situation of the reservoir to construct the reservoir geology.

[0082] In this step, the sand filling port 127 of the model shell 11 can be opened, and sand of different densities can be filled into the cavity of the model shell 11. Depending on the interlayer conditions of the simulated oil reservoir, interlayer materials such as sandstone and mudstone can be arranged to simulate different oil layer development characteristics, reservoir properties, and heterogeneity.

[0083] Before constructing the reservoir geology, the corresponding vertical simulation wells 14, steam injection horizontal simulation wells 15, and / or production horizontal simulation wells 16 are connected inside the model shell 11 according to the type of test to be conducted. Any excess simulation wells can be removed or left unconnected to avoid affecting fluid flow.

[0084] Vacuuming: After the reservoir geological construction is completed, the cavity of the model shell 11 is evacuated by vacuum pump 114.

[0085] In this step, the fourth on / off valve 113 is opened, and the vacuum pump 114 is turned on to evacuate the inside of the model housing 11.

[0086] To obtain the porosity within the cavity: the first solution is filled into the piston tank 22, the second pipeline 23 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14, the fourth pipeline 31 is connected to the first connector 18 corresponding to another vertical simulated well 14, the second back pressure valve 32 is controlled to the required test pressure, and the pressurization unit 26 is turned on to drive the first solution in the piston tank 22 into the cavity of the model housing 11. The porosity is calculated by the amount of the first solution filled and the volume of the cavity of the model housing 11.

[0087] In the above steps, the fourth connector 220 of the second pipeline 23 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14, and the fifth connector 222 of the fourth pipeline 31 is connected to the first connector 18 corresponding to another vertical simulated well 14. The second back pressure valve 32 is controlled to the required test pressure by the fourth pressure gauge 33. Then, the sixth on / off valve 216 between the pressurization unit 26 and the piston water tank 22 is opened, and the pipeline between the second pipeline 23 and one of the vertical simulated wells 14 is connected. The pressurization unit 26 is turned on to drive the first solution in the piston water tank 22 into the cavity of the model shell 11. The porosity is calculated by the amount of the first solution filled by the second flow meter 24 and the volume of the cavity of the model shell 11.

[0088] To obtain the permeability within the cavity: During the process of obtaining the porosity within the cavity, the pressurization unit 26 is activated to drive the first solution in the piston tank 22 into the cavity of the model housing 11. The injection rate of the first solution is changed, and the pressure difference is obtained based on the pressure values ​​of the second pressure gauge 25 and the fourth pressure gauge 33. The permeability within the cavity is then obtained using Darcy's formula.

[0089] Obtaining saturation: After filling the cavity of the model housing 11 with the first solution, the third pipeline 27 is connected to the third connector 112 of the production horizontal simulation well 16, and the fourth pipeline 31 is connected to the first connector 18 corresponding to one of the vertical simulation wells 14. The second back pressure valve 32 is controlled to the required test pressure, and the pressurization unit 26 is turned on to drive the crude oil in the piston oil tank 21 into the cavity of the model housing 11. The injection volume of crude oil is measured by the third flow meter 28. When the crude oil and the first solution flow steadily into the first recovery container 34, the pressurization unit 26 is turned off. The saturation of the first solution and the crude oil in the cavity of the model housing 11 are obtained based on the crude oil and the first solution in the first recovery container 34, the injection volume of crude oil and the filling volume of the first solution.

[0090] In the above steps, this step can be performed after obtaining the porosity or permeability within the cavity. The fifth connector 222 at the end of the third pipeline 27 is connected to the third connector 112 of the production horizontal simulated well 16, and the fifth connector 222 of the fourth pipeline 31 is connected to the first connector 18 corresponding to one of the vertical simulated wells 14. The second back pressure valve 32 is controlled to the required test pressure using the fourth pressure gauge 33. Then, the pipelines formed by the third pipeline 27 and the fourth pipeline 31 are connected. The seventh on / off valve 217 between the outlet of the pressurization unit 26 and the inlet of the piston oil tank 21 is opened, activating the pressurization unit 26 to drive the crude oil in the piston oil tank 21 into the cavity of the model shell 11. Through the above steps, the reservoir pressure within the model shell 11 can be precisely controlled.

[0091] The above methods can be used to obtain parameters such as porosity, permeability, and saturation of the constructed reservoir geology, which are then used to simulate the basic oil geology parameters required for different thermal recovery methods.

[0092] Depending on the different thermal recovery methods, the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs can conduct different thermal recovery tests. For example, the experimental method of the thermal recovery simulation experimental device for oil sands and extra-heavy oil reservoirs also includes the following steps: Steam injection test: First, connect the fifth pipeline 213 to the first connector 18 corresponding to one of the vertical simulated wells 14, adjust the pressure regulating valve 215 to the required test pressure, turn on the pressurization unit 26 to inject the steam generated by the steam generator 212 into the cavity of the model shell 11 through the vertical simulated well 14; after the steam injection is completed, connect the fourth pipeline 31 to the first connector 18 corresponding to the vertical simulated well 14, adjust the second back pressure valve 32 to the test pressure, connect the fourth pipeline 31 to the vertical simulated well 14 to extract the crude oil in the cavity, and record the crude oil extraction amount through the fourth flow meter 35 to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe 4 and pressure probe 5.

[0093] For example, the experimental method of the thermal recovery simulation test device for oil sands and super-heavy oil reservoirs may include the following steps: Steam drive test: Connect the fifth pipeline 213 to the first joint 18 corresponding to one of the vertical simulated wells 14, and connect the fourth pipeline 31 to the first joint 18 corresponding to another vertical simulated well 14. Adjust the pressure regulating valve 215 to the required test pressure, and turn on the pressurization unit 26 to inject the steam generated by the steam generator 212 into the cavity of the model shell 11 through the vertical simulated well 14; collect crude oil through the fourth pipeline 31 and the other vertical simulated well 14, and record the crude oil output through the fourth flow meter 35 to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe 4 and the pressure probe 5.

[0094] For example, the experimental method of the thermal recovery simulation test device for oil sands and super-heavy oil reservoirs may include the following steps: SAGD test: Connect the fifth pipeline 213 to the second joint 110 of the steam injection horizontal simulation well 15, and connect the fourth pipeline 31 to the third joint 112 of the production horizontal simulation well 16; adjust the pressure regulating valve 215 to the required test pressure, turn on the pressurization unit 26 to inject the steam generated by the steam generator 212 into the cavity of the model shell 11 through the steam injection horizontal simulation well 15, collect crude oil through the fourth pipeline 31 and the production horizontal simulation well 16, and record the crude oil production through the fourth flow meter 35 to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe 4 and the pressure probe 5.

[0095] During the various thermal recovery tests described above, the model shell 11 can be preheated to the required test temperature via the first heating unit 120, the piston water tank 22 can be heated to the required test temperature via the second heating unit 210, and the piston oil tank 21 can be heated to the required test temperature via the third heating unit 211. This ensures that the first solution and crude oil input into the model shell 11 are both at the required test temperature, thus simulating different thermal recovery test conditions at different temperatures. Furthermore, a pressure regulating valve 215 is installed at the outlet of the steam generator 212 to control the steam pressure and temperature injected during the oil sands and super-heavy oil production simulation process.

[0096] The oil sands and extra-heavy oil reservoir thermal recovery simulation experimental apparatus and method described in this application can construct different oil sands and extra-heavy oil reservoirs and obtain parameters such as porosity, permeability, and saturation of the constructed reservoir geology. These parameters are then used to simulate the conditions under different thermal recovery methods under high temperature and high pressure. Knowing the corresponding porosity, permeability, and saturation parameters, the oil sands and extra-heavy oil reservoir thermal recovery simulation experimental apparatus can simulate different gas injection methods such as steam huff and puff, steam drive, and SAGD, and finally obtain the remaining crude oil reserves.

[0097] For steam injection, this application can select a vertical simulated well 14 as the injection production well. Additional horizontal and vertical simulated wells 14 can be disassembled via quick-connect couplings. The outlet of the steam generator 212 is connected to the vertical simulated well 14, realizing a steam injection, shut-in, and production injection process. For steam drive, this application can select one or more vertical simulated wells 14 as injection wells and one or more vertical simulated wells 14 as production wells. The fifth pipeline 213 of the steam generator 212 outlet is connected to the injection wells, and the fourth pipeline 31 is connected to the production wells, realizing steam-driven oil recovery. For SAGD, the fifth pipeline 213 of the steam generator 212 outlet is connected to the steam injection horizontal simulated well 15, and the fourth pipeline 31 is connected to the production horizontal simulated well 16, realizing the SAGD injection-production process. Specifically, the quick-connect coupling allows for different connection methods, enabling the simulation of various development processes, such as SAGD development process, vertical well steam injection development process, vertical well steam drive development process (single-well gas injection for single-well oil production), vertical well steam drive development process (single-well gas injection for multi-well oil production), vertical well steam drive development process (multi-well gas injection for single-well oil production), and vertical well gas injection for horizontal well oil production / horizontal well gas injection for vertical well oil production development process.

[0098] All articles and references disclosed herein, including patent applications and publications, are incorporated herein by reference for various purposes. The term “substantially constitutes…” used to describe a combination should include the identified element, component, part, or step, as well as other elements, components, parts, or steps that do not substantially affect the essential novelty of the combination. The use of the terms “comprising” or “including” to describe combinations of elements, components, parts, or steps herein also contemplates embodiments substantially constituted by such elements, components, parts, or steps. The use of the term “may” herein is intended to indicate that any described attribute “may” include is optional. Multiple elements, components, parts, or steps can be provided by a single integrated element, component, part, or step. Alternatively, a single integrated element, component, part, or step can be divided into multiple separate elements, components, parts, or steps. The disclosure of “a” or “an” used to describe an element, component, part, or step does not imply exclusion of other elements, components, parts, or steps.

[0099] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on its differences from other embodiments. Similar or identical parts between embodiments can be referred to interchangeably. The above embodiments are only for illustrating the technical concept and features of this application, and are intended to enable those skilled in the art to understand the content of this application and implement it accordingly. They should not be construed as limiting the scope of protection of this application. All equivalent changes or modifications made in accordance with the spirit and essence of this application should be included within the scope of protection of this application.

Claims

1. A simulation experimental device for thermal recovery of oil sand and extra-heavy oil reservoirs, wherein, The simulated experimental setup for thermal recovery of oil sands and ultra-heavy oil reservoirs includes: A three-dimensional geological simulation model includes: a model shell with a cavity, the model shell being filled with sand, and the model shell having a vacuum pump interface and a recovery interface; at least two vertical simulation wells, one steam injection horizontal simulation well, and one production horizontal simulation well that can be installed within the shell; each of the vertical simulation wells having a first on / off valve and a first connector sequentially connected to its end outside the model shell; each steam injection horizontal simulation well having a second on / off valve and a second connector sequentially connected to its end outside the model shell; each production horizontal simulation well having a third on / off valve and a third connector sequentially connected to its end outside the model shell; a vacuum pump connected to the vacuum pump interface via a fourth on / off valve; a first pipeline connected to the recovery interface, the first pipeline being equipped with a fifth on / off valve, a first back pressure valve, a first pressure gauge, and a first flow meter; and a first heating unit for heating the model shell. The injection unit includes: a piston oil tank; a piston water tank; a second pipeline connected to the piston water tank, the second pipeline being equipped with a second flow meter and a second pressure gauge, and the second pipeline being connectable to a first connector corresponding to one of the vertical simulated wells; a pressurization unit for pressurizing the piston oil tank and the piston water tank; a third pipeline connected to the piston oil tank, the third pipeline being equipped with a third flow meter and a third pressure gauge, and the third pipeline being connectable to the third connector; a second heating unit for heating the piston water tank; and a third heating unit for heating the piston oil tank. The recovery unit includes: a fourth pipeline, on which a second back pressure valve and a fourth pressure gauge are installed, the fourth pipeline being used to connect to the first connector corresponding to one of the vertical simulated wells; and a first recovery container for collecting the material discharged from the fourth pipeline.

2. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 1, wherein, A fourth flow meter is installed on the fourth pipeline; The injection unit includes: a steam generator that can be connected to the piston tank; a fifth pipeline connected to the steam generator, the fifth pipeline being equipped with a fifth flow meter and a pressure regulating valve; the fifth pipeline is used to connect to the first connector corresponding to one of the vertical simulated wells; The simulated experimental setup for thermal recovery of oil sands and ultra-heavy oil reservoirs includes: Multiple temperature and pressure probes are inserted at different positions inside the model housing.

3. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 2, wherein, The oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a steam injection test state. In the steam injection test state, the fifth pipeline is first connected to the first joint corresponding to one of the vertical simulated wells, and the pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the vertical simulated well under the action of the pressurization unit. After the steam injection is completed, the fourth pipeline is then connected to the first joint corresponding to the vertical simulated well, and the second back pressure valve is adjusted to the test pressure to extract crude oil and record the crude oil extraction volume through the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

4. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 2, wherein, The oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a steam drive test state. In the steam drive test state, the fifth pipeline is connected to the first joint corresponding to one of the vertical simulated wells, and the fourth pipeline is connected to the first joint corresponding to another vertical simulated well. The pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the vertical simulated well under the action of the pressurization unit. Crude oil is collected through the fourth pipeline and the other vertical simulated well, and the crude oil production is recorded by the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

5. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 2, wherein, The oil sands and super-heavy oil reservoir thermal recovery simulation experimental device has a SAGD test state. In the SAGD test state, the fifth pipeline is connected to the second joint of the steam injection horizontal simulation well, and the fourth pipeline is connected to the third joint of the production horizontal simulation well. The pressure regulating valve is adjusted to the required test pressure, so that the steam generated by the steam generator is injected into the cavity of the model shell through the steam injection horizontal simulation well under the action of the pressurization unit. Crude oil is collected through the fourth pipeline and the production horizontal simulation well, and the crude oil production is recorded through the fourth flow meter. The temperature probe and the pressure probe are used to collect temperature and pressure changes during the experiment.

6. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 5, wherein, The model housing has a first transparent window on its side wall, and the position of the first transparent window corresponds to the position of the steam injection level simulation well and the production level simulation well.

7. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to claim 3 or 4, wherein, The model housing has a second transparent window on its side wall, and the position of the second transparent window corresponds to the position of the vertical simulated well.

8. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to any one of claims 1 to 6, wherein, The end of each of the vertical simulated wells is connected to the first on / off valve via a first quick-connect fitting; The end of the steam injection horizontal simulation well is connected to the second on / off valve via a second quick-connect coupling; The end of the production level simulation well is connected to the third on / off valve via a third quick-connect fitting.

9. The oil sand and extra-heavy oil reservoir thermal recovery simulation experiment device according to any one of claims 2 to 6, wherein, The second heating unit is also used to heat the steam generator, and the second heating unit is an air bath heating device.

10. An experimental method using the oil sand and super heavy oil reservoir thermal recovery simulation experimental device as claimed in claim 1, wherein, Includes the following steps: Reservoir geological construction: Sand is filled into the cavity of the model shell and interlayer material is arranged according to the interlayer situation of the reservoir to construct the reservoir geology; Vacuuming: After the geological construction of the reservoir is completed, the cavity of the model shell is evacuated using a vacuum pump; To obtain the porosity within the cavity: the first solution is filled into the piston tank, the second pipeline is connected to the first connector corresponding to one of the vertical simulated wells, the fourth pipeline is connected to the first connector corresponding to the other vertical simulated well, the second back pressure valve is controlled to the required test pressure, the pressurization unit is turned on to drive the first solution in the piston tank into the cavity of the model shell, and the porosity is calculated by the amount of the first solution filled and the volume of the cavity of the model shell. To obtain the permeability within the cavity: During the process of obtaining the porosity within the cavity, the pressurization unit is activated to drive the first solution in the piston tank into the cavity of the model shell. The injection rate of the first solution is changed, and the pressure difference is obtained based on the pressure values ​​of the second and fourth pressure gauges. Then, the permeability within the cavity is obtained using Darcy's formula. Obtaining saturation: After the cavity of the model shell is filled with the first solution, the third pipeline is connected to the third connector of the production horizontal simulation well, and the fourth pipeline is connected to the first connector corresponding to one of the vertical simulation wells. The second back pressure valve is controlled to the required test pressure, and the pressurization unit is turned on to drive the crude oil in the piston oil tank into the cavity of the model shell. The injection volume of crude oil is measured by the third flow meter. When the crude oil and the first solution flow steadily into the first recovery container, the pressurization unit is turned off. The saturation of the first solution and the crude oil in the cavity of the model shell are obtained according to the crude oil and the first solution in the first recovery container, the injection volume of crude oil and the filling volume of the first solution.

11. The experimental method of the oil sand and super-heavy oil reservoir thermal recovery simulation experimental apparatus according to claim 10, wherein, A fourth flow meter is installed on the fourth pipeline; The injection unit includes: a steam generator that can be connected to the piston tank; a fifth pipeline connected to the steam generator, the fifth pipeline being equipped with a fifth flow meter and a pressure regulating valve; the fifth pipeline is used to connect to the first connector corresponding to one of the vertical simulated wells; Multiple temperature and pressure probes are inserted at different positions inside the model housing.

12. The experimental method of the oil sand and super-heavy oil reservoir thermal recovery simulation experimental apparatus according to claim 11, wherein, The experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device also includes the following steps: Steam injection test: First, connect the fifth pipeline to the first connector corresponding to one of the vertical simulated wells, adjust the pressure regulating valve to the required test pressure, and turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the vertical simulated well; after the steam injection is completed, connect the fourth pipeline to the first connector corresponding to the vertical simulated well, adjust the second back pressure valve to the test pressure, connect the fourth pipeline to the vertical simulated well to extract crude oil from the cavity, and record the crude oil extraction amount through the fourth flow meter to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

13. The experimental method of the oil sand and super-heavy oil reservoir thermal recovery simulation experimental apparatus according to claim 11, wherein, The experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device also includes the following steps: Steam drive test: Connect the fifth pipeline to the first connector corresponding to one of the vertical simulated wells, and connect the fourth pipeline to the first connector corresponding to the other vertical simulated well. Adjust the pressure regulating valve to the required test pressure, and turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the vertical simulated well. Collect crude oil through the fourth pipeline and the other vertical simulated well, and record the crude oil output through the fourth flow meter to obtain the remaining crude oil reserves. Collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

14. The experimental method of the oil sand and extra-heavy oil reservoir thermal recovery simulation experimental apparatus according to claim 11, wherein, The experimental method of the oil sands and ultra-heavy oil reservoir thermal recovery simulation experimental device also includes the following steps: SAGD Test: Connect the fifth pipeline to the second joint of the steam injection horizontal simulation well, and connect the fourth pipeline to the third joint of the production horizontal simulation well; adjust the pressure regulating valve to the required test pressure, turn on the pressurization unit to inject the steam generated by the steam generator into the cavity of the model shell through the steam injection horizontal simulation well, collect crude oil through the fourth pipeline and the production horizontal simulation well, and record the crude oil output through the fourth flow meter to obtain the remaining crude oil reserves; collect the temperature and pressure changes during the experiment through the temperature probe and the pressure probe.

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