A simulation system and method for enhanced oil recovery by pressure drive in oil reservoirs

Abstract

This application provides a reservoir pressure-driven enhanced oil recovery simulation system and method, relating to the field of petroleum development. The reservoir pressure-driven enhanced oil recovery simulation system includes a test formation that can simulate an actual oilfield. It utilizes pressure-driven technology to expand the pores of the reservoir containing the oil sample by pressurizing the test formation. Various pressure-driven fluids are injected into the test formation, and the recovery rate corresponding to each fluid is determined based on the mixture produced. By comparing the recovery rates of different pressure-driven fluids, the reservoir pressure-driven enhanced oil recovery simulation system can identify the most suitable pressure-driven fluid for the current test formation. When the oil sample is crude oil, this pressure-driven fluid can maximize the extraction of crude oil from the oilfield, thereby improving the oil recovery rate.

Description

Technical Field

[0001] This application relates to the field of petroleum development, and in particular to a reservoir pressure-driven enhanced oil recovery simulation system and method. Background Technology

[0002] During oilfield development, the recovery rate of crude oil in conventional sandstone reservoirs after waterflooding is generally 30%-40%, leaving a large amount of residual oil in the reservoir. Pressure flooding (PFD) is a technique proposed in recent years to increase reservoir utilization and improve crude oil recovery. PFD involves injecting a large volume of liquid carrying a displacement agent into the formation under high pressure and at low flow rates, creating a pressure gradient that drives the crude oil remaining in the reservoir towards the production well. This alters the wettability between the formation and the fluid, increasing the driving pressure and kinetic energy of the reservoir. Increased production is achieved through pressure diffusion and the full replacement of crude oil in the reservoir pores by the displacement agent. However, different oilfields require different PFD fluids. Currently, it is impossible to determine the appropriate PFD fluid for a particular oilfield. Summary of the Invention

[0003] In view of this, this application provides a reservoir pressure-driven enhanced oil recovery simulation system and method, the main purpose of which is to determine the pressure-driven fluid with the best pressure-driven effect and improve the oilfield development effect.

[0004] To achieve the above objectives, the first aspect of this application discloses a reservoir pressure-driven enhanced oil recovery simulation system, comprising:

[0005] The formation to be tested contains reservoir pores, and the reservoir pores contain oil samples to be recovered.

[0006] An adjustment component is connected to the formation to be tested. The adjustment component is used to pressurize the formation to be tested to expand the reservoir porosity, and to inject various pressure-driven fluids into the formation to be tested so that the pressure-driven fluids displace the oil sample to be recovered from the reservoir porosity to obtain a corresponding mixture, the mixture including the oil sample to be recovered and the pressure-driven fluid.

[0007] A controller is configured to acquire the recovery rate of the oil sample to be recovered corresponding to each of the mixtures, and compare the recovery rates to determine a target hydraulic fluid suitable for the formation to be tested, wherein the target hydraulic fluid is at least one of the plurality of hydraulic fluids.

[0008] Optionally, the formation to be tested includes multiple different surfaces, and the adjustment component is used to pressurize the formation to be tested from different surfaces respectively, and to inject multiple pressure-driven fluids into the formation to be tested from any surface respectively.

[0009] Optionally, there may be one or more adjustment components. When there are multiple adjustment components, each of the surfaces of the formation to be tested is provided with an inlet, and one adjustment component is connected to at least one of the inlets.

[0010] Optionally, the adjustment component includes:

[0011] The injection device is connected to the formation to be tested, and the injection device stores a variety of pressure-driven fluids.

[0012] A pressurization device is connected to the formation to be tested and the injection device, respectively. The pressurization device is used to pressurize the formation to be tested to expand the reservoir porosity and to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, displacing the oil sample to be produced from the reservoir porosity to obtain a mixture, the mixture comprising the oil sample to be produced and the pressure-driven fluid.

[0013] Optional, the injection device includes:

[0014] Multiple liquid storage tanks are provided, each of which is connected to the pressurization device and the formation to be tested. The liquid storage tanks are used to store the pressure-driven fluid, and the pressure-driven fluid stored in each of the liquid storage tanks is different.

[0015] Optional, sample collection device;

[0016] A sampling device is connected to the formation to be tested. The sampling device is used to collect the mixture and determine the parameters to be tested of the mixture, including volume.

[0017] Optionally, it includes multiple stacked unit strata, with adjacent unit strata separated from each other on their sides, and each unit strata is provided with a removable baffle on its periphery. The stratum to be tested is composed of at least one of the unit strata.

[0018] For all of the unit formations, when the adjustment assembly pressurizes the formation to be tested, the baffle is configured to move out of the unit formation.

[0019] Optionally, the system further includes: a pressurization chamber and a pressurization plate;

[0020] The pressurization chamber connects the adjustment assembly and the pressurization plate, and the pressurization plate is connected to the baffle.

[0021] When the baffle is removed, the pressurization chamber deforms as the adjustment assembly pressurizes the formation to be tested, so that the pressurization plate expands the reservoir porosity in the unit formation by pushing the unit formation.

[0022] The second aspect of this application discloses a reservoir pressure-driven enhanced oil recovery simulation method, applied to the reservoir pressure-driven enhanced oil recovery simulation system of the first aspect, and executed in the system's controller, including:

[0023] Obtain the recovery rate of the oil sample to be recovered for each of the aforementioned mixtures;

[0024] The various recovery rates are compared to determine the target hydraulic fluid that is compatible with the formation to be tested, wherein the target hydraulic fluid is at least one of the various hydraulic fluids.

[0025] Optionally, the regulating assembly includes an injection device and a pressurization device. The injection device is connected to the formation to be tested. When the pressurization device is connected to both the formation to be tested and the injection device, before obtaining the recovery rate of the oil sample corresponding to each of the mixtures, the assembly further includes:

[0026] The pressurization device is controlled to pressurize the formation to be tested to expand the reservoir porosity, and the pressurization device is controlled to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, thereby displacing the oil sample to be recovered from the reservoir porosity to obtain a mixture, the mixture comprising the oil sample to be recovered and the pressure-driven fluid.

[0027] A third aspect of this application provides an electronic device, comprising:

[0028] At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor to enable the at least one processor to perform the method of any one of the second aspects disclosed.

[0029] A fourth aspect of this application provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method described in the second aspect.

[0030] In summary, based on the technical solution disclosed in this application, and addressing the technical problem of different pressure-driven fluids suitable for different oilfields, this application provides a reservoir pressure-driven enhanced oil recovery simulation system. This system can determine the most suitable pressure-driven fluid for the tested formation through simulation testing. The system includes: a tested formation containing reservoir pores and an oil sample to be recovered; an adjustment component connected to the tested formation, used to pressurize the tested formation to expand the reservoir pores and to inject various pressure-driven fluids into the tested formation to displace the oil sample from the reservoir pores, resulting in a corresponding mixture, which includes the oil sample and the pressure-driven fluid; and a controller used to acquire the recovery rate of the oil sample corresponding to each mixture and compare the recovery rates to determine the target pressure-driven fluid suitable for the tested formation, wherein the target pressure-driven fluid is at least one of several pressure-driven fluids. The reservoir pressure-driven enhanced oil recovery simulation system provided in this application includes a test formation that can simulate an actual oilfield. It utilizes pressure-driven technology to expand the pores of the reservoir containing the oil sample by pressurizing the test formation. Various pressure-driven fluids are injected into the test formation, and the recovery rate corresponding to each fluid is determined based on the resulting mixture. By comparing the recovery rates of different pressure-driven fluids, the most suitable fluid for the current test formation is identified, thus providing strong data support for oilfield development. Attached Figure Description

[0031] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0032] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, for those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0033] Figure 1 The structure of the reservoir pressure-driven enhanced oil recovery simulation system provided in this application embodiment is shown. Figure 1 ;

[0034] Figure 2 This illustration shows a schematic diagram of pressurization of the formation to be tested provided in an embodiment of this application;

[0035] Figure 3 This illustration shows a schematic diagram of pressurization and fluid injection into the formation to be tested, provided in an embodiment of this application.

[0036] Figure 4 The structure of the reservoir pressure-driven enhanced oil recovery simulation system provided in this application embodiment is shown. Figure 2 ;

[0037] Figure 5 shows the structure of the reservoir pressure drive enhanced oil recovery simulation system provided in the embodiment of this application. Figure 3 ;

[0038] Figure 6 shows the structure of the reservoir pressure drive enhanced oil recovery simulation system provided in the embodiment of this application. Figure 4 ;

[0039] Figure 7 A flowchart of the reservoir pressure drive enhanced oil recovery simulation method provided in the embodiments of this application is shown. Detailed Implementation

[0040] To better understand the technical solutions provided in the embodiments of this specification, the technical solutions of the embodiments of this specification will be described in detail below with reference to the accompanying drawings and specific embodiments. It should be understood that the embodiments of this specification and the specific features in the embodiments are detailed descriptions of the technical solutions of the embodiments of this specification, rather than limitations on the technical solutions of this specification. In the absence of conflict, the embodiments of this specification and the technical features in the embodiments can be combined with each other.

[0041] In this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, without necessarily requiring or implying any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element. The term "two or more" includes two or more cases.

[0042] In oilfield development, waterflooding is widely used due to its ability to replenish formation energy promptly and its cost-effectiveness. However, the recovery rate of conventional sandstone reservoir waterflooding is generally only 30%-40%, leaving a large amount of crude oil remaining in the reservoir. To further improve the effectiveness of waterflooding, pressure flooding technology can be applied to enhance oil recovery. Pressure flooding technology injects a large amount of liquid carrying a displacement agent into the formation at high pressure and low flow rate, creating a pressure gradient that drives the crude oil remaining in the reservoir towards the production well. This alters the wettability between the formation and the fluid adhering to the reservoir pores, increasing the driving pressure and kinetic energy of the reservoir. Through pressure diffusion and the full replacement of crude oil in the reservoir pores by the displacement agent, the goal of increased production is achieved.

[0043] However, the type of hydraulic displacement fluid suitable for different rock formations in different oilfields varies depending on factors such as lithology, mineral types, and water saturation. Furthermore, the complex environment at the extraction site makes it difficult to test and determine the most suitable hydraulic displacement fluid.

[0044] To address the aforementioned technical issues, this embodiment proposes an oil reservoir pressure-driven enhanced oil recovery simulation system, which can be used to simulate oilfield strata. By injecting various pressure-driven fluids into the strata, the system determines the pressure-driven fluid corresponding to the highest recovery rate based on the produced mixture, thus serving as the pressure-driven fluid most suitable for the oilfield.

[0045] The reservoir pressure-driven enhanced oil recovery simulation system proposed in this embodiment, such as Figure 1 As shown, it includes:

[0046] Formation 11 to be tested contains reservoir pores, and oil samples to be extracted are contained within the reservoir pores.

[0047] The regulating component 12 is connected to the formation to be tested 11. The regulating component 12 is used to pressurize the formation to be tested 11 to expand the reservoir pores, and to inject various pressure-driven fluids into the formation to be tested so that the pressure-driven fluids displace the oil sample to be produced from the reservoir pores to obtain a corresponding mixture, the mixture including the oil sample to be produced and the pressure-driven fluid.

[0048] The controller 13 is used to acquire the recovery rate of the oil sample to be produced corresponding to each mixture and compare the recovery rates to determine the target pressure driving fluid that is compatible with the formation to be tested. The target pressure driving fluid is at least one of a variety of pressure driving fluids.

[0049] In the system, the formation to be tested 11 is used to simulate the rock formations in an actual oilfield. The formation to be tested can be a simulated rock formation artificially created to mimic actual rock formations. The reservoir pores of the formation to be tested 11 store oil samples to be recovered. These oil samples can be oil samples artificially injected into the formation beforehand. When the oil samples are in the formation to be tested 11, the vast majority adhere to the reservoir pores of the formation.

[0050] The regulating component in this embodiment can be used to pressurize the formation to be tested, thereby expanding the reservoir porosity. After the reservoir porosity expands, a hydraulic displacement fluid is injected into the formation. The hydraulic displacement fluid can fully contact the oil sample to be recovered in the formation and displace the oil sample from the reservoir porosity. The hydraulic displacement fluid can be of various types, which can refer to different types of hydraulic displacement fluids or different concentrations. For example, different types of hydraulic displacement fluids can be solutions containing chemicals such as polymers (polyacrylamide), nanofluids (nano silica), and surfactants (alkylbenzene sulfonates). The chemicals in the solution are used to change the wettability between the formation and the fluids attached to the reservoir porosity, reducing the saturation of crude oil in the residual fluid (different chemicals have different degrees of change in the wettability of the core and fluid, thus leading to different final oil recovery rates).

[0051] After injecting pressure-driven fluid into the formation to be tested, a mixture will be extracted from the formation. The mixture contains the oil sample to be extracted from the formation, the pressure-driven fluid that has not been fully replaced, and other liquid impurities.

[0052] In some embodiments, the system further includes: a sample collection device; the sample collection device is connected to the formation to be tested, the sample collection device is used to collect the mixture and determine the parameters to be tested of the mixture, the parameters to be tested including: volume.

[0053] After the mixture is extracted from the formation to be tested, it is collected into a sampling device. After being settled and filtered in the sampling device, the volume of the oil sample to be extracted can be obtained directly or indirectly.

[0054] After acquiring the volume of the oil sample to be recovered, the controller can calculate the recovery rate of the oil sample. For example, when calculating the recovery rate, if the oil sample injected into the formation is artificially injected, then the total volume of the oil sample to be recovered is V, and the volume of the recovered oil sample acquired by the controller is V0. The recovery rate η can then be expressed as:

[0055]

[0056] The enhanced oil recovery (EOR) simulation system using reservoir pressure flooding can test the EOR corresponding to various pressure flooding fluids. During each oil sample acquisition process, the test formation needs to be replaced; the replacement formation is almost identical to the original, and an additional oil sample is added to the test formation. By comparing the EOR corresponding to various pressure flooding fluids, the most suitable pressure flooding fluid for the current test formation is determined. This allows for rapid identification of the optimal pressure flooding fluid with relatively low testing costs, improving testing efficiency.

[0057] In some embodiments, the formation to be tested includes multiple different surfaces, and the adjustment component is used to pressurize the formation to be tested from different surfaces, and to inject multiple pressure-driven fluids into the formation to be tested from any surface.

[0058] In the process of pressurizing and injecting pressure-driven fluid into the formation to be tested, the technical solution of this embodiment combines multiple surfaces of the formation to be tested to adjust the pressurization and injection methods.

[0059] This embodiment proposes pressurizing the formation under test from multiple directions during the pressurization process. In one embodiment, confining pressure can be applied to the formation under test from multiple directions to achieve rapid pressurization, thereby rapidly expanding the reservoir porosity in the formation. For example, when the formation under test is a regular hexahedron, confining pressure can be applied to the six surfaces of the formation under test via the x-axis, y-axis, and z-axis of the hexahedron, respectively. For example,... Figure 2 As shown, Figure 2 The cube represents the formation to be measured, and the x-axis, y-axis, and z-axis of the formation to be measured represent the pressure direction of the confining pressure applied to the formation.

[0060] When injecting hydraulic displacement fluid into the formation under test, to simulate the actual hydraulic displacement fluid injection process in an oilfield, the injected fluid is only injected through one surface of the formation under test. However, the selected surface of the formation under test can be any surface. For example, when the formation under test is a regular hexahedron, the hydraulic displacement fluid can be injected from left to right or from right to left. Injection from left to right and injection from right to left represent opposite directions, and injection from left to right and injection from right to left represent reverse hydraulic displacement. Current hydraulic displacement simulation devices are mostly designed with a single target when performing the injection hydraulic displacement fluid step, meaning they can only simulate hydraulic displacement in one direction or one layer. Such simulation devices cannot fully reflect the bidirectional nature of the actual reservoir hydraulic displacement process: 1. Forward hydraulic displacement involves injecting chemical hydraulic displacement fluid at high pressure from the injection end, expanding the swept volume in the formation, causing the hydraulic displacement fluid to collect scattered residual oil along the displacement direction and continue to drive it to the production end. After the pressure displacement process is completed, the injection end resumes normal water injection operation. 2. Reverse pressure displacement involves injecting chemical displacement fluid at high pressure from the production end. Single-target simulation methods are insufficient to accurately assess the fluid interactions between different pressure displacement directions and their impact on oil displacement efficiency. Pressure displacement typically requires different media (such as nanofluids, surfactants, polymers, foam displacement agents, alkaline solutions, composite displacement agents, etc.) and multi-site injection methods to determine the recovery rate of the formation under test. Existing simulation devices cannot perform multi-directional injection of pressure displacement fluid during injection, thus failing to determine the optimal injection direction.

[0061] In some embodiments, multiple surfaces of a first test formation can be pressurized to expand reservoir porosity. Then, a pressure-driven fluid is injected into the first test formation in a first direction to harvest the mixture and calculate a first recovery rate. Similarly, multiple surfaces of a second test formation can be pressurized to expand reservoir porosity. Then, a pressure-driven fluid is injected into the second test formation in a second direction to harvest the mixture and calculate a second recovery rate. The first and second test formations are the same formation; the first and second directions are opposite to each other. By comparing the first and second recovery rates, the optimal recovery rate can be determined when injecting pressure-driven fluid in different directions into the same test formation. By obtaining the optimal recovery rates corresponding to various pressure-driven fluids, the optimal injection direction for using the pressure-driven fluid can be further determined based on the determination of the most suitable pressure-driven fluid.

[0062] In some embodiments, there are one or more adjustment components. When there are multiple adjustment components, each surface of the formation to be tested is provided with an inlet, and one adjustment component is connected to at least one inlet.

[0063] Since the formation under test can have multiple surfaces, the regulating components can simultaneously pressurize or inject hydraulic displacement fluid into the formation through each surface. To achieve orderly control during pressurization or injection of hydraulic displacement fluid, this embodiment can provide at least one set of regulating components, and at least one set of regulating components is connected to an inlet. For example, such as... Figure 3 As shown, Figure 3 The middle stratum 31 to be tested contains multiple surfaces. Figure 3 The solid line represents pressurization of the formation to be tested, and the dashed line represents injection of pressure-driven fluid into the formation. The regulating component 32 can pressurize the formation 31 to be tested through multiple surfaces and inject pressure-driven fluid into the formation 31 to be tested through its left side. The regulating component 32 can also pressurize the formation 31 to be tested through multiple surfaces and inject pressure-driven fluid into the formation 31 to its right side.

[0064] In some embodiments, the regulating component includes:

[0065] The injection device is connected to the formation to be tested, and the injection device stores a variety of pressure-driven fluids.

[0066] The pressurization device is connected to the formation to be tested and the injection device respectively. The pressurization device is used to pressurize the formation to be tested to expand the reservoir pores and to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, displacing the oil sample to be produced from the reservoir pores to obtain a mixture, which includes the oil sample to be produced and the pressure-driven fluid.

[0067] The regulating assembly further includes a liquid injection device and a pressurization device. In addition to directly pressurizing the formation to be tested, the pressurization device can further pressurize the liquid injection device to drive the pressure-driven fluid stored in the liquid injection device into the formation to be tested.

[0068] In some embodiments, the injection device includes: a plurality of storage tanks, each of which is connected to a pressurization device, the storage tanks are connected to the formation to be tested, the storage tanks are used to store pressure-driven fluid, and the pressure-driven fluids stored in the plurality of storage tanks are different.

[0069] The injection device has multiple storage tanks that can hold various pressure-driven fluids. The pressurization device can pressurize the selected storage tank and push the pressure-driven fluid in the storage tank to be injected into the formation to be tested.

[0070] For example, such as Figure 4 As shown, Figure 4 The pressurization device consists of a motor 41 and an air pump 42. The high-pressure gas output by the air pump can pass through the air inlet 431. Figure 4 Five air inlets are shown in the diagram, which are injected into the formation 43 to be tested. The injection device includes storage tanks 441, 442, and 443. High-pressure gas output from the air pump can also push the pressure-driven fluid in storage tank 441 through the guide hole 432 into the formation 43 to be tested. A flow sensor 433 can also be installed at the guide hole to monitor the flow rate of the pressure-driven fluid injected into the formation 43 to be tested.

[0071] In some embodiments, Figure 4 The test formation 43 also includes a sample outlet 434, which is connected to a sample collection device 45 and is used to collect the mixed liquid extracted from the test formation 43.

[0072] In some embodiments, the reservoir pressure drive enhanced oil recovery simulation system is provided with a box, in which multiple stacked unit formations are provided. Each unit formation can be a core or a rock slab. The sides of two adjacent unit formations that are close to each other are separated from each other. The periphery of each unit formation is provided with a removable baffle. The formation to be tested is composed of at least one of the unit formations.

[0073] For all unit formations in the chamber, when the regulating component pressurizes and injects fluid into the formation to be tested, the baffle is configured to move out of the unit formation.

[0074] The formation to be tested can be housed within a container, which can contain multiple formations stacked vertically, each containing a rock layer. Any number of adjacent unit formations within the container can be combined as the test formation. A horizontal baffle is installed between adjacent unit formations, allowing them to connect when the baffle is removed. A baffle is also installed around the perimeter of each unit formation perpendicular to the horizontal direction, preventing the pressurizing device from pressurizing and injecting fluid into the unit formation. For example, such as... Figure 5aAs shown in Figures 51-56, the baffles between unit formations are shown in Figure 57, and the baffles around the perimeter of a unit formation are shown in Figure 58. During the simulation test, any number of adjacent unit formations from baffles 51-56 can be selected. Figure 5b Select unit strata 54 and 55, and remove the baffle between unit strata 54 and 55, as well as the baffle around unit strata 54 and 55.

[0075] Using the technical solution of this embodiment, any number of unit formations can be used as the test formations. Furthermore, identical rock plates can be installed between adjacent formations to arbitrarily expand or reduce the thickness of the rock plates, thus allowing for arbitrary adjustment of the test formations. The reservoir pressure-driven enhanced oil recovery simulation system in this embodiment can have multiple unit formations, which can be arbitrarily selected to simulate different actual formation conditions using any number of unit formation combinations.

[0076] In some embodiments, the housing further includes: a pressurizing chamber and a pressurizing plate;

[0077] The pressurization chamber is connected to the adjustment assembly and the pressurization plate, and the pressurization plate is connected to the baffle.

[0078] When the baffle is removed, the pressurization chamber deforms as the regulating component pressurizes the formation to be tested, so that the pressurization plate expands the reservoir porosity in the unit formation by pushing the unit formation.

[0079] This embodiment further illustrates the specific pressurization method for the formation under test. The reservoir pressure-driven enhanced oil recovery simulation system in this embodiment uses a pressure plate to push and compress the formation under test, thereby achieving reservoir porosity expansion within the formation. For example, as shown... Figure 6a As shown, the pressurization chamber in the housing is 61, the pressurization plate is 62, and the housing contains unit formations 63-68. The pressurization chamber includes a first pressurization chamber 611 and a second pressurization chamber 612. The first pressurization chamber 611 is used to directly pressurize one unit formation, and the baffle between the first pressurization chamber 611 and the unit formation is 6901. The second pressurization chamber 612 can be used to directly pressurize multiple unit formations, and the baffles between the second pressurization chamber 612 and the unit formations are 6902-6907, while the baffles between adjacent unit formations are 6908-6912. When using the reservoir pressure drive enhanced oil recovery simulation system, multiple adjacent unit formations in the housing can be identified as the formations to be tested. For example, unit formations 66 and 67 are selected as the formations to be tested. During the pressurization process of the formations to be tested, all baffles can be removed, and air can be introduced through the air inlet 431 (e.g., Figure 4 The air intake shown is Figure 6aFour air inlets (located on the upper, lower, left, and right surfaces of the housing) pressurize all unit formations 63-68. The first pressurizing chamber 611 and the second pressurizing chamber 612 push the pressurizing plate 62 to pressurize each unit formation, thus pressurizing all unit formations. After pressurization, baffles 6901, 6902-6904, 6907, 6908-6910, and 6912 are installed, as shown in Figure 6(b). Pressure-driven fluid is then injected into the formation to be tested. When injecting the pressure-driven fluid into the formation, it enters the housing through the guide hole 432 on the housing and then through the guide holes installed in the formation to be tested. The guide holes (as shown in Figures 631, 641, 651, 661, 671, and 681) can be installed in each unit formation. A production end (e.g., at the opposite end where the pressure-driven fluid is injected into the formation to be tested) is provided. Figure 4 As shown in 434), it is used to output the mixed fluid produced from the formation under test. The reservoir pressure-driven enhanced oil recovery simulation system of this embodiment can optimize the pressurization effect of any unit formation in the tank through three-dimensional pressurization, so as to facilitate better reservoir porosity expansion in any unit formation. When injecting pressure-driven fluid into any formation under test, the output of the most oil samples is achieved.

[0080] This application discloses a reservoir pressure-driven enhanced oil recovery simulation method, applied to a reservoir pressure-driven enhanced oil recovery simulation system, and executed by the system's controller, such as... Figure 7 As shown, it includes:

[0081] Step 701: Obtain the recovery rate of the oil sample to be recovered for each mixture.

[0082] The controller directs the injection of hydraulic fluid into the formation to be tested, and a mixture is extracted from the formation, containing the oil sample to be recovered. The oil sample in the formation can be injected manually, and the recovery rate is calculated by the ratio of the extracted oil sample to the injected oil sample.

[0083] By injecting various hydraulic displacement fluids into the formation to be tested, the recovery rate corresponding to each hydraulic displacement fluid is determined. For example, the injected hydraulic displacement fluid may be a 5% concentration polymer (polyacrylamide), nanofluid (nano silica), or surfactant (alkylbenzene sulfonate).

[0084] Step 702: Compare the various recovery rates to determine the target hydraulic fluid that is compatible with the formation to be tested. The target hydraulic fluid is at least one of a variety of hydraulic fluids.

[0085] In some embodiments, the recovery rate of the tested formation is related not only to the type of hydraulic fluid but also to the injection direction of the hydraulic fluid. When the same hydraulic fluid is injected into the tested formation via a first direction or a second direction, the recovered oil samples will differ. The recovery rates of the oil samples recovered from the tested formation are shown in Table 1.

[0086] Table 1. Recovery rates corresponding to different injection directions and pressure-driven fluids.

[0087]

[0088] As shown in Table 1, the recovery rate was highest when alkylbenzene sulfonate was used as the pressure driving fluid in the No. 1 rock formation and the pressure driving fluid was injected from the first direction.

[0089] By comparing the recovery rates of various hydraulic displacement fluids, the most suitable hydraulic displacement fluid for the current formation under test is determined. When the oil sample to be recovered is crude oil, this hydraulic displacement fluid can be used to maximize the extraction of crude oil from the oil field and improve the crude oil recovery rate.

[0090] In some embodiments, the regulating assembly includes an injection device and a pressurization device, wherein the injection device is connected to the formation to be tested, and the pressurization device is connected to both the formation to be tested and the injection device, and before obtaining the recovery rate of the oil sample corresponding to each mixture, the assembly further includes:

[0091] The pressurization device is controlled to pressurize the formation to be tested to expand the reservoir pores, and the pressurization device is controlled to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, displacing the oil sample to be produced from the reservoir pores to obtain a mixture, which includes the oil sample to be produced and the pressure-driven fluid.

[0092] In addition to determining the hydraulic displacement fluid based on the recovery rate, the controller can also control the reservoir hydraulic displacement enhanced oil recovery simulation system. It controls the pressurization device to pressurize the formation under test, expanding the reservoir porosity. It can also control the pressurization device to push the hydraulic displacement fluid from the injection device into the formation under test, displacing the oil sample to be recovered from the reservoir porosity.

[0093] It should be noted that the descriptions of each embodiment in the above embodiments have different focuses. For parts that are not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0094] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-readable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-readable program code.

[0095] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded computer, 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 a machine for implementing the flowchart illustrations. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0096] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0097] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0098] This application also provides a computer program product, which includes computer software instructions that, when executed on a processing device, cause the processing device to execute a process of a reservoir pressure drive enhanced oil recovery simulation method.

[0099] A computer program product includes one or more computer instructions. When the computer program instructions are loaded and executed on a computer, all or part of the flow or function according to the embodiments of this application is generated. The computer may be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. The computer instructions may be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, computer instructions may be transmitted from one website, computer, server, or data center to another website, computer, server, or data center via wired (e.g., coaxial cable, fiber optic, digital subscriber line (DSL)) or wireless (e.g., infrared, wireless, microwave, etc.) means. The computer-readable storage medium may be any available medium that a computer can store or a data storage device such as a server or data center that integrates one or more available media. The available medium may be a magnetic medium (e.g., floppy disk, hard disk, magnetic tape), an optical medium (e.g., DVD), or a semiconductor medium (e.g., solid-state disk (SSD)).

[0100] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0101] In the several embodiments provided in this application, it should be understood that the disclosed devices, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, or indirect coupling or communication connection between devices or units, and may be electrical, mechanical, or other forms.

[0102] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0103] Furthermore, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0104] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0105] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application.

[0106] Although preferred embodiments have been described in this specification, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including the preferred embodiments as well as all changes and modifications falling within the scope of this specification.

[0107] Obviously, those skilled in the art can make various modifications and variations to this specification without departing from its spirit and scope. Therefore, if such modifications and variations fall within the scope of the claims and their equivalents, this specification is also intended to include such modifications and variations.

Claims

1. A reservoir pressure-driven enhanced oil recovery simulation system, characterized in that, include: The formation to be tested contains reservoir pores, and the reservoir pores contain oil samples to be recovered. An adjustment component is connected to the formation to be tested. The adjustment component is used to pressurize the formation to be tested to expand the reservoir porosity, and to inject various pressure-driven fluids into the formation to be tested so that the pressure-driven fluids displace the oil sample to be recovered from the reservoir porosity to obtain a corresponding mixture, the mixture including the oil sample to be recovered and the pressure-driven fluid. A controller is configured to acquire the recovery rate of the oil sample to be recovered corresponding to each of the mixtures, and compare the recovery rates to determine a target hydraulic fluid suitable for the formation to be tested, wherein the target hydraulic fluid is at least one of the plurality of hydraulic fluids.

2. The system according to claim 1, characterized in that, The formation to be tested includes multiple different surfaces, and the adjustment component is used to pressurize the formation to be tested from different surfaces, and to inject multiple pressure-driven fluids into the formation to be tested from any surface.

3. The system according to claim 2, characterized in that, The adjustment component may be one or more. When there are multiple adjustment components, each surface of the formation to be tested is provided with an inlet, and one adjustment component is connected to at least one inlet.

4. The system according to claim 1, characterized in that, The adjustment component includes: The injection device is connected to the formation to be tested, and the injection device stores a variety of the pressure-driven fluids. A pressurization device is connected to the formation to be tested and the injection device, respectively. The pressurization device is used to pressurize the formation to be tested to expand the reservoir porosity and to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, displacing the oil sample to be produced from the reservoir porosity to obtain the mixture, which includes the oil sample to be produced and the pressure-driven fluid.

5. The system according to claim 4, characterized in that, The injection device includes: Multiple liquid storage tanks are provided, each of which is connected to the pressurization device and the formation to be tested. The liquid storage tanks are used to store the pressure-driven fluid, and the pressure-driven fluid stored in each of the liquid storage tanks is different.

6. The system according to claim 1, characterized in that, Also includes: A sampling device is connected to the formation to be tested. The sampling device is used to collect the mixture and determine the parameters to be tested of the mixture, including volume.

7. The system according to claim 1, characterized in that, It includes multiple stacked unit strata, with adjacent unit strata separated from each other on their sides, and each unit strata has a removable baffle on its periphery. The stratum to be tested is composed of at least one of the unit strata. For all of the unit formations, when the adjustment assembly pressurizes the formation to be tested, the baffle is configured to move out of the unit formation.

8. The system according to claim 7, characterized in that, Also includes: Pressure chamber and pressure plate; The pressurizing chamber is connected to the adjusting assembly and the pressurizing plate, and the pressurizing plate is connected to the baffle. When the baffle is removed, the pressurization chamber deforms as the adjustment assembly pressurizes the formation to be tested, so that the pressurization plate pushes the unit formation and expands the reservoir porosity in the unit formation.

9. A method for enhancing oil recovery through pressure flooding in an oil reservoir, characterized in that, Applied to the reservoir pressure-driven enhanced oil recovery simulation system as described in any one of claims 1 to 8, and executed in the system's controller, the method includes: Obtain the recovery rate of the oil sample to be recovered for each mixture; The various recovery rates are compared to determine the target hydraulic fluid that is compatible with the formation to be tested, wherein the target hydraulic fluid is at least one of the various hydraulic fluids.

10. The method according to claim 9, characterized in that, The regulating assembly includes an injection device and a pressurization device. The injection device is connected to the formation to be tested. When the pressurization device is connected to both the formation to be tested and the injection device, before obtaining the recovery rate of the oil sample corresponding to each mixture, it further includes: The pressurization device is controlled to pressurize the formation to be tested to expand the reservoir porosity, and the pressurization device is controlled to pressurize the injection device to allow the pressure-driven fluid to enter the formation to be tested, thereby displacing the oil sample to be produced from the reservoir porosity to obtain a mixture, wherein the mixture includes the oil sample to be produced and the pressure-driven fluid.

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