Methods and systems for heavy oil extraction, storage media, and terminals

Abstract

The present application discloses a method and system for exploiting heavy oil, a storage medium, and a terminal, which relate to the technical field of steam-assisted gravity drainage. The main purpose is to improve the existing problem that due to the inability to form a unified vapor-liquid interface, steam channeling is likely to occur, making the regulation and control difficult, and further reducing the heavy oil recovery rate. The method includes: obtaining the length information of the horizontal section of a horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of vertical steam injection wells; determining the length parameters of the production well section according to the length information of the horizontal section of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and dividing the horizontal production well into multiple production well sections based on the length parameters of the production well section; monitoring the height parameters of the steam cavity in real time, and controlling the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameters of the steam cavity.

Description

Technical Field

[0001] The present application relates to the technical field of steam-assisted gravity drainage, and particularly to a method and system for exploiting heavy oil, a storage medium, and a terminal. Background Art

[0002] Steam-assisted gravity drainage (SAGD) uses steam as a heat source and relies on the gravity of asphalt and condensate to exploit heavy oil. Since highly viscous crude oil has no flow capacity under the original formation conditions, first, a thermal connection needs to be formed between the injection and production wells (to raise the reservoir temperature to a temperature at which the crude oil can flow); further, after the thermal connection is formed, high-quality steam is continuously injected into the reservoir from the steam injection well, so as to form a steam chamber in the formation, and rely on the upward and lateral movement of the steam chamber to exchange heat with the crude oil in the reservoir, so that the heated crude oil and steam condensate flow to the lower production well for production by gravity. Because steam-assisted gravity drainage has the technical characteristics of high recovery rate and high oil production rate, it is one of the most successful thermal recovery technologies in the development of heavy oil and oil sands at present, and has been regarded as the standard technology for the development of heavy oil and oil sands and has been widely applied.

[0003] At present, when exploiting heavy oil in horizontal production wells with a large elevation difference in the horizontal section based on steam-assisted gravity drainage, due to the inability to form a unified vapor-liquid interface, steam channeling is likely to occur, increasing the control difficulty and further reducing the recovery rate of heavy oil. Summary of the Invention

[0004] In view of this, the present application provides a method and system for exploiting heavy oil, a storage medium, and a terminal, mainly aiming to improve the technical problem that in the existing situation, due to the inability to form a unified vapor-liquid interface, steam channeling is likely to occur, increasing the control difficulty and further reducing the recovery rate of heavy oil.

[0005] According to one aspect of the present application, a method for exploiting heavy oil is provided, including:

[0006] Obtaining the length information of the horizontal section of a horizontal production well, the angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of vertical steam injection wells;

[0007] Determining the length parameter of the production well section according to the length information of the horizontal section of the horizontal production well, the angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and dividing the horizontal production well into multiple production well sections based on the length parameter of the production well section;

[0008] Real-time monitoring the height parameter of the steam chamber, and controlling the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameter of the steam chamber.

[0009] Preferably, before determining the length parameter of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, the method further includes:

[0010] Based on multiple preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction, respectively, obtain multiple alternative production well section length parameters;

[0011] Calculate the height parameters of the steam cavities corresponding to each of the alternative production well section length parameters according to each of the alternative production well section length parameters;

[0012] Calculate the horizontal advance distance parameters of each of the steam cavities according to the height parameters of the steam cavities corresponding to each of the alternative production well section length parameters;

[0013] Calculate the recovery factor corresponding to each of the alternative production well section length parameters according to the height parameters and horizontal advance distance parameters of the steam cavities corresponding to each of the alternative production well section length parameters.

[0014] Preferably, the determining the length parameter of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells specifically includes:

[0015] Determine the length parameter of the production well section according to the recovery factor corresponding to each of the alternative production well section length parameters and the spacing information of the vertical steam injection wells.

[0016] Preferably, before the height parameter of the steam cavity is monitored in real time and the multiple production well sections are controlled to carry out heavy oil exploitation in sequence according to the height parameter of the steam cavity, the method further includes:

[0017] Perform preheating treatment on the horizontal production well and the vertical steam injection wells, and monitor the formation pressure parameter and the inter-well temperature parameter in real time;

[0018] If the formation pressure parameter reaches the preset formation pressure parameter threshold and the inter-well temperature parameter reaches the preset inter-well temperature parameter threshold, then control the first production well section in the multiple production well sections to enter the heavy oil exploitation stage.

[0019] Preferably, the monitoring the height parameter of the steam cavity in real time and controlling the multiple production well sections to carry out heavy oil exploitation in sequence according to the height parameter of the steam cavity specifically includes:

[0020] Monitor the height parameter of the steam cavity in real time;

[0021] If the height parameter of the steam cavity reaches a preset height parameter threshold, control the next production well section to enter the heavy oil exploitation stage.

[0022] Preferably, the real-time monitoring of the height parameter of the steam cavity specifically includes:

[0023] Obtain the temperature and pressure data of the steam cavity in real time;

[0024] Calculate the real-time height parameter of the steam cavity based on the temperature and pressure data.

[0025] Preferably, the method further includes:

[0026] Real-time monitor and adjust the height parameter of the vapor-liquid interface above the horizontal production well so that the height parameter of the vapor-liquid interface is within a preset vapor-liquid interface height parameter threshold.

[0027] According to another aspect of the present application, a heavy oil exploitation system is provided, including:

[0028] An acquisition module, configured to acquire the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells;

[0029] A division module, configured to determine the length parameter of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and divide the horizontal production well into multiple production well sections based on the length parameter of the production well section;

[0030] An oil production module, configured to real-time monitor the height parameter of the steam cavity and control the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameter of the steam cavity.

[0031] Preferably, before the division module, the system further includes:

[0032] A calculation module, configured to respectively obtain multiple alternative production well section length parameters based on multiple preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction;

[0033] The calculation module is further configured to respectively calculate the height parameter of the steam cavity corresponding to each of the alternative production well section length parameters according to each of the alternative production well section length parameters;

[0034] The calculation module is further configured to calculate the horizontal advancement distance parameters of the steam cavities respectively according to the height parameters of the steam cavities corresponding to the respective alternative production well section length parameters.

[0035] The calculation module is further configured to calculate the recovery factor corresponding to each of the alternative production well section length parameters respectively according to the height parameters and the horizontal advancement distance parameters of the steam cavities corresponding to the respective alternative production well section length parameters.

[0036] Preferably, the partitioning module is specifically configured to:

[0037] Determine the length parameter of the production well section according to the recovery factor corresponding to each of the alternative production well section length parameters and the spacing information of the vertical steam injection wells.

[0038] Preferably, before the oil production module, the system further includes:

[0039] A preheating module, configured to perform preheating treatment on the horizontal production well and the vertical steam injection wells, and to monitor the formation pressure parameter and the inter-well temperature parameter in real time.

[0040] The preheating module is further configured to, if the formation pressure parameter reaches a preset formation pressure parameter threshold and the inter-well temperature parameter reaches a preset inter-well temperature parameter threshold, control the first production well section among the multiple production well sections to enter the heavy oil production stage.

[0041] Preferably, the oil production module specifically includes:

[0042] A monitoring unit, configured to monitor the height parameter of the steam cavity in real time.

[0043] A switching drive unit, configured to, if the height parameter of the steam cavity reaches a preset height parameter threshold, control the next production well section to enter the heavy oil production stage.

[0044] Preferably, the monitoring unit specifically includes:

[0045] An acquisition subunit, configured to acquire the temperature and pressure data of the steam cavity in real time.

[0046] A calculation subunit, configured to calculate the real-time height parameter of the steam cavity based on the temperature and pressure data.

[0047] Preferably, the system further includes:

[0048] A monitoring module, configured to monitor and adjust the height parameter of the vapor-liquid interface above the horizontal production well in real time, so that the height parameter of the vapor-liquid interface is within a preset vapor-liquid interface height parameter threshold.

[0049] According to another aspect of the present application, there is provided a storage medium storing at least one executable instruction, and the executable instruction causes a processor to perform operations corresponding to the above-mentioned heavy oil extraction method.

[0050] According to still another aspect of the present application, there is provided a terminal, including: a processor, a memory, a communication interface, and a communication bus, and the processor, the memory, and the communication interface complete communication with each other through the communication bus;

[0051] The memory is used to store at least one executable instruction, and the executable instruction causes the processor to perform operations corresponding to the above-mentioned heavy oil extraction method.

[0052] By means of the above technical solutions, the technical solutions provided by the embodiments of the present application have at least the following advantages:

[0053] The present application provides a heavy oil extraction method, system, storage medium, and terminal. First, obtain the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells; secondly, determine the length parameter of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and divide the horizontal production well into multiple production well sections based on the length parameter of the production well section; finally, monitor the height parameter of the steam cavity in real time, and control the multiple production well sections to sequentially extract heavy oil according to the height parameter of the steam cavity. Compared with the prior art, the embodiments of the present application determine the optimal production well section length parameter according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, divide the horizontal production well into multiple production well sections according to the optimal production well section length parameter, and further control the multiple production well sections to sequentially extract heavy oil according to the real-time height parameter of the steam cavity. Through the segmented steam-assisted gravity drainage extraction method, there is no need to form a unified steam-liquid interface, avoiding the occurrence of steam channeling, and at the same time increasing the swept range of the steam cavity, thereby improving the recovery rate of heavy oil.

[0054] The above description is only an overview of the technical solutions of the present application. In order to be able to understand the technical means of the present application more clearly, it can be implemented according to the content of the specification. And in order to make the above and other purposes, features, and advantages of the present application more obvious and understandable, the following specifically describes the embodiments of the present application. BRIEF DESCRIPTION OF THE DRAWINGS

[0055] Upon reading the following detailed description of the preferred embodiments, various other advantages and benefits will become apparent to those of ordinary skill in the art. The accompanying drawings are only for the purpose of showing the preferred embodiments and are not considered to be a limitation of the present application. Moreover, throughout the drawings, the same reference numerals are used to represent the same components. In the drawings:

[0056] Figure 1 A flowchart of a method for exploiting heavy oil provided by an embodiment of the present application is shown;

[0057] Figure 2 An arrangement diagram of a horizontal production well and a vertical steam injection well provided by an embodiment of the present application is shown;

[0058] Figure 3 The positional relationship between the horizontal production well and the vertical steam injection well provided by an embodiment of the present application is shown;

[0059] Figure 4 A schematic diagram of the spacing between vertical steam injection wells provided by an embodiment of the present application is shown;

[0060] Figure 5 A flowchart of another method for exploiting heavy oil provided by an embodiment of the present application is shown;

[0061] Figure 6 A comparison table of alternative production well section parameters provided by an embodiment of the present application is shown;

[0062] Figure 7 A schematic diagram of the relationship between the vapor-liquid interface and the steam cavity provided by an embodiment of the present application is shown;

[0063] Figure 8 The schematic diagram of the target height of the vapor-liquid interface provided by an embodiment of the present application is shown Figure 1 ;

[0064] Figure 9 The schematic diagram of the target height of the vapor-liquid interface provided by an embodiment of the present application is shown Figure 2 ;

[0065] Figure 10 A block diagram of the composition of a heavy oil exploitation system provided by an embodiment of the present application is shown;

[0066] Figure 11 A schematic diagram of the structure of a terminal provided by an embodiment of the present application is shown. Detailed Embodiments

[0067] Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided so that the present disclosure can be more thoroughly understood and the scope of the present disclosure can be completely conveyed to those skilled in the art.

[0068] At the same time, it should be understood that, for the sake of convenience of description, the dimensions of the various parts shown in the drawings are not drawn in actual proportional relationship.

[0069] The following description of at least one exemplary embodiment is actually merely illustrative and in no way restricts the present application and its application or use.

[0070] Technologies, methods, and devices known to those of ordinary skill in the relevant art may not be discussed in detail, but where appropriate, the said technologies, methods, and devices should be regarded as part of the specification.

[0071] It should be noted that: like reference numerals and letters denote like items in the following drawings, and thus, once an item is defined in one drawing, it does not need to be further discussed in subsequent drawings.

[0072] Embodiments of the present application can be applied to a computer system / server, which can operate with numerous other general-purpose or special-purpose computing system environments or configurations. Examples of well-known computing systems, environments, and / or configurations suitable for use with a computer system / server include, but are not limited to: personal computer systems, server computer systems, thin clients, thick clients, handheld or laptop devices, microprocessor-based systems, set-top boxes, programmable consumer electronics, network personal computers, minicomputer systems, mainframe computer systems, and distributed cloud computing technology environments including any of the above systems, and so on.

[0073] The computer system / server can be described in the general context of computer system-executable instructions, such as program modules, executed by a computer system. Generally, program modules can include routines, programs, object programs, components, logic, data structures, and so on, which perform specific tasks or implement specific abstract data types. The computer system / server can be implemented in a distributed cloud computing environment where tasks are executed by remote processing devices linked through a communication network. In a distributed cloud computing environment, program modules can be located on local or remote computing system storage media including storage devices.

[0074] Embodiments of the present application provide a method for exploiting heavy oil, as Figure 1 shown, the method includes:

[0075] 101. Obtain the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells.

[0076] Generally, the steam-assisted gravity drainage system is composed of a combination of vertical steam injection wells and horizontal production wells, and the layout is as Figure 2 shown. Among them, the vertical steam injection wells are used to inject steam into the reservoir, and the horizontal production wells are used to produce oil. In the embodiments of the present application, the horizontal section length information of the horizontal production well is used to characterize the length information between point A and point B as shown in Figure 3 ; the included angle information between the horizontal section of the horizontal production well and the horizontal direction is used to characterize the α angle as shown in Figure 3 ; the spacing information of the vertical steam injection wells is used to characterize the spacing information between two dots as shown in Figure 4 (such as 70 m). In the embodiments of the present application, the current execution end can be the control end of the reservoir exploitation platform. Before exploiting the reservoir, relevant parameters of the vertical steam injection wells and the horizontal production wells are collected in advance.

[0077] It should be noted that the horizontal production wells and the vertical steam injection wells are pre-arranged based on the development of the reservoir, the distribution characteristics of the oil layer and the interlayer, etc.

[0078] 102. Determine the length parameters of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and divide the horizontal production well into multiple production well sections based on the length parameters of the production well section.

[0079] When heavy oil is exploited from a horizontal production well with a large height difference in the horizontal section based on steam-assisted gravity drainage, a unified steam-liquid interface cannot be formed, which easily leads to steam channeling, increasing the regulation difficulty and reducing the recovery rate of heavy oil. Based on this, in the embodiments of the present application, by reasonably dividing the horizontal production well into multiple production well sections and performing oil production in sequence in a segmented manner, the above problems can be effectively avoided. It should be noted that to prevent the steam cavity from entering the horizontal production well, a certain height of liquid level needs to be maintained above the horizontal production well, and the liquid level is calculated based on the highest point of the horizontal section. According to simulation studies, when the horizontal section of the horizontal production well has the same length, the development effect of SAGD is inversely proportional to the height difference of the horizontal section of the horizontal production well. Therefore, the smaller the height difference of the horizontal section of the horizontal production well, the better the SAGD development effect. Specifically, when the height difference of the horizontal section of the horizontal production well is not greater than 10 m, the recovery rate can reach more than 55%, and at this time, a better development effect can be obtained. However, according to the formula L i =Δh i / sinα where L i represents the length parameter of the production well section, Δhi i represents the elevation difference of the horizontal section of the horizontal production well, and α represents the angle information between the horizontal section of the horizontal production well and the horizontal direction. It can be seen that as the elevation difference of the horizontal section of the horizontal production well decreases, the length parameter of the production well section also decreases. However, too short a length parameter of the production well section will result in an inability to match the vertically arranged steam injection wells that have been pre-arranged. Therefore, it is necessary to determine the final length parameter of the production well section in combination with the spacing information of the vertically arranged steam injection wells and divide the horizontal production well.

[0080] 103. Real-time monitor the height parameter of the steam cavity and control multiple production well sections to carry out heavy oil exploitation in sequence according to the height parameter of the steam cavity.

[0081] In the embodiment of the present application, the conversion timing of the production well section is judged according to the development of the steam cavity (i.e., the height parameter) to carry out segmented heavy oil exploitation, without forming a unified steam-liquid interface, avoiding the occurrence of steam channeling.

[0082] Compared with the prior art, in the embodiment of the present application, the optimal length parameter of the production well section is determined according to the length information of the horizontal section of the horizontal production well, the angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertically arranged steam injection wells. The horizontal production well is divided into multiple production well sections according to the optimal length parameter of the production well section. Further, according to the real-time height parameter of the steam cavity, multiple production well sections are controlled to carry out heavy oil exploitation in sequence. Through the segmented steam-assisted gravity drainage exploitation method, there is no need to form a unified steam-liquid interface, avoiding the occurrence of steam channeling, and at the same time increasing the swept range of the steam cavity, thereby improving the recovery rate of heavy oil.

[0083] The embodiment of the present application provides another heavy oil exploitation method, as Figure 5 shown. This method includes:

[0084] 201. Obtain the length information of the horizontal section of the horizontal production well, the angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertically arranged steam injection wells.

[0085] This step in the embodiment of the present application is the same as step 101 in the embodiment and will not be elaborated here.

[0086] 202. According to the length information of the horizontal section of the horizontal production well, the angle information between the horizontal section of the horizontal production well and the horizontal direction, and multiple preset alternative production well section elevation difference parameters, calculate the alternative production well section length parameters and recovery rates corresponding to each alternative production well section elevation difference parameter respectively.

[0087] According to simulation studies, when the horizontal section of a horizontal production well has the same length, the development effect of SAGD is inversely proportional to the elevation difference of the horizontal section of the horizontal production well. Therefore, the smaller the elevation difference of the horizontal section of the horizontal production well, the better the SAGD development effect. However, according to the formula L i = Δh i / sinα (where L i represents the length parameter of the production well section, Δh i represents the elevation difference of the horizontal section of the horizontal production well, and α represents the angle information between the horizontal section of the horizontal production well and the horizontal direction), it can be seen that as the elevation difference of the horizontal section of the horizontal production well decreases, the length parameter of the production well section also decreases. However, an overly short length parameter of the production well section will result in an inability to match the pre-arranged vertical steam injection wells. Therefore, it is necessary to determine the final length parameter of the production well section in combination with the spacing information of the vertical steam injection wells and divide the horizontal production well. Specifically, multiple alternative elevation difference parameters of the production well section can be set in advance according to historical experience. For example, 2m, 3m, 4m, 5m. Then, based on the length information of the horizontal section of the horizontal production well and the angle information between the horizontal section of the horizontal production well and the horizontal direction, the alternative production well section length parameters corresponding to each alternative elevation difference parameter of the production well section can be calculated according to the formula L i = Δh i / sinα, as shown in Figure 6 ; further, based on each alternative production well section length parameter, the height parameter of the steam chamber corresponding to each alternative production well section length parameter can be calculated according to the formula (where β represents the available head coefficient, γ represents the expansion angle of the steam chamber, K represents the effective permeability of the oil phase, v s represents the kinematic viscosity of the crude oil at the steam temperature, m represents the dimensionless viscosity-temperature correlation coefficient, α represents the thermal diffusivity of the oil reservoir, Φ represents the porosity of the oil reservoir, ΔS0 represents the movable oil saturation at the steam temperature, h represents the thickness of the oil reservoir above the horizontal section, and t represents the production time); further, based on the formula x = h 汽腔 tg(γ), the horizontal advancement distance parameter of each steam chamber can be obtained; finally, based on the height parameter and horizontal advancement distance parameter of each steam chamber obtained above, according to the formula (where x represents the horizontal advancement distance parameter of the steam chamber, h represents the height parameter of the steam chamber, A is generally a constant with a value of 0.7 - 0.8, Φ represents the porosity of the oil reservoir, and S0 represents the movable oil saturation at the steam temperature) and (where N P represents the heavy oil reserves), the recovery factor corresponding to each alternative production well section length parameter can be calculated.

[0088] Correspondingly, step 202 of the embodiment specifically includes: respectively obtaining a plurality of alternative production well section length parameters based on a plurality of preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction; respectively calculating the height parameters of the steam cavities corresponding to the respective alternative production well section length parameters according to the respective alternative production well section length parameters; respectively calculating the horizontal advancement distance parameters of the respective steam cavities according to the height parameters of the steam cavities corresponding to the respective alternative production well section length parameters; and respectively calculating the recovery rates corresponding to the respective alternative production well section length parameters according to the height parameters and the horizontal advancement distance parameters of the steam cavities corresponding to the respective alternative production well section length parameters.

[0089] 203. Determine the length parameter of the production well section according to the recovery rate corresponding to each alternative production well section length parameter and the spacing information of the vertical steam injection wells; and divide the horizontal production well into a plurality of production well sections based on the length parameter of the production well section.

[0090] In the implementation of this application, the alternative production well section length parameters obtained in step 202 of the embodiment can be screened according to the spacing information of the vertical steam injection wells arranged at the mining site, and the obviously inconsistent ones can be screened out. For example, if the spacing of the vertical steam injection wells is 70 m, then the alternative production well section length parameter of 46 (as Figure 6 shown) can be screened out; further, the remaining alternative production well section length parameters are secondarily screened according to the recovery rate. It should be noted that the final length parameter of the production well section can also be determined by predicting the resources required for adding vertical steam injection wells and the resources obtained from oil production, and after weighing and comparing. Finally, the horizontal production well is divided into a plurality of production well sections according to the final length parameter of the production well section. In addition, when injecting gas through the vertical steam injection wells, all the steam injection wells can be enabled, or sparse enabling (such as interval enabling) can be performed.

[0091] 204. Preheating preparation stage.

[0092] It should be noted that due to the high viscosity of heavy oil, it has no flow ability under formation conditions, and the low temperature and high pressure of the oil layer, it is necessary to preheat and reduce the pressure before switching to SAGD production, so that thermal connection is formed between the injection and production wells. In addition, in order to mobilize the inter-well oil layer as much as possible and expand the lateral mobilization range, so as to be more conducive to the connection of the steam chamber after the conversion drive, in the embodiment of the present application, by adopting unified preheating, steam throughput or steam circulation preheating methods are adopted in horizontal production wells, and steam throughput preheating methods are adopted in vertical steam injection wells. Further, when the formation pressure parameter reaches the preset formation pressure parameter threshold (such as 3-4MPa), and the inter-well temperature parameter reaches the preset inter-well temperature parameter threshold (such as 80-100°C, that is, the horizontal well and the surrounding vertical wells are thermally connected), it indicates that the underground temperature field is formed, and at this time, the first production well section can be transferred to the heavy oil production stage.

[0093] Correspondingly, step 204 of the embodiment specifically includes: preheating the horizontal production wells and the vertical steam injection wells, and monitoring the formation pressure parameters and the interwell temperature parameters in real time; if the formation pressure parameter reaches a preset formation pressure parameter threshold, and the interwell temperature parameter reaches a preset interwell temperature parameter threshold, then controlling the first production well section among the multiple production well sections to enter the heavy oil production stage.

[0094] 205. Monitor the height parameters of the steam chamber in real time, and control multiple production well sections to carry out heavy oil production in sequence according to the height parameters of the steam chamber.

[0095] In the embodiment of the present application, when the first production well section enters the heavy oil production stage, the formula (where β represents the available pressure head coefficient, γ represents the expansion angle of the steam chamber, K represents the effective permeability of the oil phase, and v s (expressed as the kinematic viscosity of crude oil at steam temperature, m as the dimensionless viscosity-temperature correlation coefficient, α as the thermal diffusion coefficient of the oil layer, Φ as the oil layer porosity, ΔS0 as the movable oil saturation at steam temperature, h as the thickness of the oil layer above the horizontal section, and t as the production time) to judge the development of the steam chamber. When the height parameter of the steam chamber reaches the lower limit of the steam perforation of the vertical steam injection well corresponding to the second production well section, the second production well section is controlled to enter the heavy oil production stage, and the corresponding vertical steam injection well continuously injects steam; at the same time, the injection hole of the vertical steam injection well corresponding to the first production well section returns to the injection hole position of the vertical steam injection well corresponding to the second production well section and continuously injects steam. The rest of the production well sections are analogous to this, realizing the heavy oil production of step-by-step upward return.

[0096] Accordingly, step 205 of the embodiment specifically includes: real-time monitoring of the height parameter of the steam chamber; if the height parameter of the steam chamber reaches a preset height parameter threshold, controlling the next production well section to enter the heavy oil production stage.

[0097] As an alternative solution, in the embodiments of the present application, the height parameter of the steam chamber is monitored in real time, specifically including: obtaining the temperature and pressure data of the steam chamber in real time; calculating the real-time height parameter of the steam chamber based on the temperature and pressure data.

[0098] As another preferred solution, in the embodiments of the present application, the method of the embodiment further includes: monitoring and adjusting in real time the height parameter of the vapor-liquid interface above the horizontal production well so that the height parameter of the vapor-liquid interface is within a preset vapor-liquid interface height parameter threshold.

[0099] It should be noted that one of the keys to the stable production of SAGD exploitation is to form a vapor-liquid interface with a certain height above the horizontal production well. If the vapor-liquid interface is too low and the liquid drainage volume is too large, steam channeling in the horizontal well is likely to occur and the steam will be produced; if the vapor-liquid interface is too high to the perforation bottom boundary of the vertical steam injection well and the liquid drainage volume is too small, the steam zone at the lower part of the steam injection well section is likely to become a liquid phase zone, thereby affecting the development of the steam chamber, as Figure 7 shown. Therefore, it is necessary to ensure that the vapor-liquid interface (i.e., the height parameter of the steam chamber) of each production well section is located at a reasonable position. Preferably, the height parameter of the steam chamber is maintained between the highest point of the production well section in production and the perforation bottom boundary of the vertical steam injection well, as Figure 8 、 Figure 9 shown. Based on this, in the embodiments of the present application, by monitoring and adjusting in real time the height parameter of the vapor-liquid interface above the horizontal production well, the above problems can be avoided, thereby improving the recovery rate of heavy oil.

[0100] Furthermore, since the height parameter of the vapor-liquid interface cannot be directly detected, the height parameter of the vapor-liquid interface can be judged by monitoring the temperature difference (Subcool) between the injected steam and the produced fluid. Specifically, through the following formula, the variation relationship between the height parameter h of the vapor-liquid interface and Subcool can be obtained, and this formula reflects the relationship between the height h of the vapor-liquid interface, Subcool, the injection-production pressure difference, and the liquid production rate

[0101]

[0102] wherein, ΔP = P s -P w represents the injection-production pressure difference, with the unit of 10 -3 MPa; P s represents the steam chamber pressure, with the unit of 10 - 3 MPa; P w represents the bottom hole pressure of the horizontal production well, with the unit of 10 -3 MPa; ρ represents the density value at a certain point in the liquid pool, with the unit of kg / m 3 ; h represents the height parameter of the vapor-liquid interface, that is, the distance between the vapor-liquid interface and the horizontal production well, with the unit of m; QL represents the liquid production rate, with the unit of m 3 / d; θ represents the included angle of the liquid pool between the injection and production wells (π - 2(β + γ) ≤ θ ≤ π - 2γ, as shown Figure 8 in the figure), with the unit of rad; K represents the effective permeability, with the unit of μm 2 ; L represents the length parameter of the production well section, with the unit of m; T w represents the temperature of the produced liquid, with the unit of °C; T s represents the steam injection temperature, with the unit of °C. Among them, taking the Liaohe heavy oil as an example, the viscosity of the crude oil at a certain point in the liquid pool can be estimated according to the following formula

[0103] ρ oi = ρ ot +(11.26 - 0.191x)×10 -3 -(53.3 - 0.9x)×10 -5 ×t 1.02

[0104] x = INT[100*(ρ t - 0.9202)]

[0105] where ρ oi represents the density of the crude oil at 20 °C on the ground, with the unit of g / cm 3 ; ρ ot represents the density of the crude oil at the corresponding temperature t, with the unit of g / cm 3 ; x represents the coefficient related to the density of the crude oil on the ground. Then the density ρ of the mixed liquid in the liquid pool = f w *ρ w +(1 - f w )ρ ot , where ρ w represents the density of water, with the unit of g / cm 3 ; ρ ot represents the density of the water-free crude oil at the temperature t, with the unit of g / cm 3 ; f w represents the water cut.

[0106] Based on the viscosity-temperature relationship of heavy oil, the relationship between μ 地层 ~μ 脱气 ~t of Liaohe heavy oil can be known. Based on this, only by the viscosities of the crude oil and the dissolved gas-oil ratio at two temperature points, the formation crude oil viscosity at different temperatures can be obtained

[0107] μ 地层 = C*μ 脱气 d

[0108] where C = 10.715*(5.615*R s + 100)-0.515

[0109] μ 脱气 = e at+b

[0110] a = (lnμ 50 - lnμ 100 ) / (t 50 - t 100 )

[0111] b = lnμ 50 - at 50

[0112] d = 5.44 * (5.615 * R s + 150) -0.338

[0113] wherein, μ 脱气 represents the viscosity of degassed crude oil (determined by laboratory experiments, generally taking the viscosity values corresponding to 50°C and 100°C), and the unit is μm 2 ; R s represents the original dissolved gas-oil ratio; μ 50 , μ 100 respectively represent the viscosities of degassed crude oil at 50°C and 100°C determined by laboratory experiments, and the unit is μm 2 ; t 50 , t 100 represents the measurement temperature of the viscosity of degassed crude oil, and the unit is °C. Based on existing field experience, it is known that the Subcoo l value is 15° - 25°, and the larger the value, the higher the vapor-liquid interface, that is, the closer to the bottom of the perforation of the steam injection well. At the same time, reservoir numerical simulation tracking is carried out, and the Subcoo l value is determined through comprehensive analysis of the monitoring data of observation wells to predict the development status of the steam cavity and timely adjust the injection and production parameters to ensure a reasonable vapor-liquid interface.

[0114] In specific application scenarios, usually, horizontal production wells with a large elevation difference in the horizontal section can be divided into two types: down-dip horizontal production wells and up-turned horizontal production wells. Among them, if the horizontal production well is a down-dip horizontal production well, a heat tracing type heavy oil production method is used for heavy oil production; if the horizontal production well is an up-turned horizontal production well, heat tracing production is not required.

[0115] It should be noted that when the up - tilted horizontal production well is exploited, the low - lying part is preferentially utilized, and the produced fluid can be produced without passing through the cold oil area. Therefore, generally, no associated heating is required for exploitation. When the down - tilted horizontal production well is exploited, the high - lying part is preferentially utilized, and the produced fluid needs to pass through the cold oil area. Due to easy heat loss along the way, problems such as an increase in wellbore viscosity are caused. Therefore, an associated - heating heavy - oil exploitation method needs to be adopted to reduce the viscosity of heavy oil. Specifically, for the associated - heating time, if the length of the production well section < the horizontal section length of the horizontal well, the associated heating can be stopped after all production well sections are utilized. For the selection of the associated - heating production well section, it is from the production well section that has not entered the oil - production stage to the lowest point. For the associated - heating method, methods such as electric heating and steam tracing can be adopted. It should be noted that when using steam tracing, the condensed water after steam injection will be produced together with the produced fluid. Therefore, the displacement of the pump needs to be appropriately considered. The displacement of the pump needs to be greater than the maximum liquid production of the well. When the temperature at any point in the horizontal section of the horizontal production well approaches the flowable temperature of the crude oil and lifting problems occur, associated heating is required to improve the fluidity of the crude oil and facilitate the smooth lifting and production of the crude oil.

[0116] The present application provides a method for exploiting heavy oil. First, information on the horizontal section length of a horizontal production well, information on the angle between the horizontal section of the horizontal production well and the horizontal direction, and information on the spacing between vertical steam - injection wells are obtained. Secondly, length parameters of the production well section are determined based on the information on the horizontal section length of the horizontal production well, the information on the angle between the horizontal section of the horizontal production well and the horizontal direction, and the information on the spacing between vertical steam - injection wells. And the horizontal production well is divided into multiple production well sections based on the length parameters of the production well section. Finally, the height parameter of the steam cavity is monitored in real time, and heavy - oil exploitation is controlled for the multiple production well sections in sequence according to the height parameter of the steam cavity. Compared with the prior art, in the embodiment of the present application, the optimal length parameters of the production well section are determined according to the information on the horizontal section length of the horizontal production well, the information on the angle between the horizontal section of the horizontal production well and the horizontal direction, and the information on the spacing between vertical steam - injection wells. The horizontal production well is divided into multiple production well sections according to the optimal length parameters of the production well section. Further, according to the real - time height parameter of the steam cavity, heavy - oil exploitation is controlled for the multiple production well sections in sequence. Through a segmented steam - assisted gravity drainage exploitation method, there is no need to form a unified vapor - liquid interface, avoiding the occurrence of steam channeling phenomenon. At the same time, the swept range of the steam cavity is increased, thereby improving the recovery rate of heavy oil.

[0117] Further, as an implementation of the above Figure 1 shown method, the embodiment of the present application provides a heavy - oil exploitation system, as Figure 10 shown, the device includes:

[0118] An acquisition module 31, a division module 32, and an oil - production module 33.

[0119] An acquisition module 31 for acquiring the horizontal section length information of a horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of vertical steam injection wells;

[0120] A division module 32 for determining the length parameters of production well sections based on the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and dividing the horizontal production well into multiple production well sections based on the length parameters of the production well sections;

[0121] An oil production module 33 for real-time monitoring of the height parameters of the steam cavity and controlling the sequential heavy oil production of the multiple production well sections according to the height parameters of the steam cavity.

[0122] Preferably, before the division module, the system further includes:

[0123] A calculation module for obtaining multiple alternative production well section length parameters respectively based on multiple preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction;

[0124] The calculation module is further configured to calculate the height parameters of the steam cavity corresponding to each of the alternative production well section length parameters respectively according to each of the alternative production well section length parameters;

[0125] The calculation module is further configured to calculate the horizontal advance distance parameters of each of the steam cavities respectively according to the height parameters of the steam cavity corresponding to each of the alternative production well section length parameters;

[0126] The calculation module is further configured to calculate the recovery factor corresponding to each of the alternative production well section length parameters respectively according to the height parameters and horizontal advance distance parameters of the steam cavity corresponding to each of the alternative production well section length parameters.

[0127] Preferably, the division module is specifically configured to:

[0128] Determine the length parameters of the production well sections according to the recovery factor corresponding to each of the alternative production well section length parameters and the spacing information of the vertical steam injection wells.

[0129] Preferably, before the oil production module, the system further includes:

[0130] A preheating module for preheating the horizontal production well and the vertical steam injection wells, and real-time monitoring of the formation pressure parameters and the inter-well temperature parameters;

[0131] The preheating module is further configured to control the first production well section among the plurality of production well sections to enter the heavy oil production stage if the formation pressure parameter reaches a preset formation pressure parameter threshold and the inter-well temperature parameter reaches a preset inter-well temperature parameter threshold.

[0132] Preferably, the oil production module specifically includes:

[0133] A monitoring unit for real-time monitoring of the height parameter of the steam cavity.

[0134] A conversion drive unit for controlling the next production well section to enter the heavy oil production stage if the height parameter of the steam cavity reaches a preset height parameter threshold.

[0135] Preferably, the monitoring unit specifically includes:

[0136] An acquisition subunit for real-time acquisition of the temperature and pressure data of the steam cavity.

[0137] A calculation subunit for calculating the real-time height parameter of the steam cavity based on the temperature and pressure data.

[0138] Preferably, the system further includes:

[0139] A monitoring module for real-time monitoring and adjustment of the height parameter of the vapor-liquid interface above the horizontal production well to make the height parameter of the vapor-liquid interface within a preset vapor-liquid interface height parameter threshold.

[0140] The present application provides a heavy oil production system. First, the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells are obtained. Secondly, the length parameter of the production well section is determined according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and the horizontal production well is divided into a plurality of production well sections based on the length parameter of the production well section. Finally, the height parameter of the steam cavity is monitored in real time, and the plurality of production well sections are controlled to sequentially carry out heavy oil production according to the height parameter of the steam cavity. Compared with the prior art, in the embodiment of the present application, the optimal length parameter of the production well section is determined according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells, and the horizontal production well is divided into a plurality of production well sections according to the optimal length parameter of the production well section. Further, according to the real-time height parameter of the steam cavity, the plurality of production well sections are controlled to sequentially carry out heavy oil production. Through the segmented steam-assisted gravity drainage production method, there is no need to form a unified vapor-liquid interface, avoiding the occurrence of steam channeling phenomenon, and at the same time increasing the swept range of the steam cavity, thereby improving the recovery rate of heavy oil.

[0141] According to an embodiment of the present application, a storage medium is provided. The storage medium stores at least one executable instruction, and the computer executable instruction can execute the heavy oil extraction method in any of the above method embodiments.

[0142] Based on such an understanding, the technical solution of the present application can be embodied in the form of a software product. The software product can be stored in a non-volatile storage medium (which can be a CD-ROM, a USB flash drive, a mobile hard disk, etc.), and includes several instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) to execute the methods described in various implementation scenarios of the present application.

[0143] Figure 11 The structure diagram of a terminal provided according to an embodiment of the present application is shown. The specific implementation of the terminal is not limited in the specific embodiments of the present application.

[0144] As Figure 11 shown, the computer device may include: a processor 402, a communication interface 404, a memory 406, and a communication bus 408.

[0145] Among them: the processor 402, the communication interface 404, and the memory 406 complete mutual communication through the communication bus 408.

[0146] The communication interface 404 is used to communicate with network elements of other devices such as clients or other servers.

[0147] The processor 402 is used to execute the program 410, and specifically can execute the relevant steps in the above-mentioned heavy oil extraction method embodiment.

[0148] Specifically, the program 410 may include program code, and the program code includes computer operation instructions.

[0149] The processor 402 may be a central processing unit CPU, or a specific integrated circuit ASIC (Application Specific Integrated Circuit), or one or more integrated circuits configured to implement the embodiments of the present application. One or more processors included in the computer device may be of the same type of processor, such as one or more CPUs; or may be of different types of processors, such as one or more CPUs and one or more ASICs.

[0150] A memory 406 for storing a program 410. The memory 406 may include high-speed RAM memory and may also include non-volatile memory, such as at least one magnetic disk memory.

[0151] The program 410 may specifically be used to cause the processor 402 to perform the following operations:

[0152] Obtain the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection well;

[0153] Determine the length parameters of the production well section according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection well, and divide the horizontal production well into multiple production well sections based on the length parameters of the production well section;

[0154] Real-time monitor the height parameters of the steam cavity, and control the multiple production well sections to perform heavy oil exploitation in sequence according to the height parameters of the steam cavity.

[0155] The storage medium may also include an operating system and a network communication module. The operating system is a program for managing the physical device hardware and software resources for the exploitation of the above heavy oil, and supports the operation of information processing programs and other software and / or programs. The network communication module is used to implement the communication between the components inside the storage medium, and the communication between other hardware and software in the information processing physical device.

[0156] Each embodiment in this specification is described in a progressive manner. The key point of each embodiment is to illustrate the differences from other embodiments. For the same or similar parts among the embodiments, reference can be made to each other. For the system embodiment, since it basically corresponds to the method embodiment, the description is relatively simple, and for the relevant parts, reference can be made to the partial description of the method embodiment.

[0157] The methods and systems of the present application may be implemented in many ways. For example, the methods and systems of the present application may be implemented through software, hardware, firmware, or any combination of software, hardware, and firmware. The above order of the steps for the method is only for illustration, and the steps of the methods of the present application are not limited to the above specific described order, unless otherwise specifically stated. In addition, in some embodiments, the present application may also be implemented as a program recorded in a recording medium, and these programs include machine-readable instructions for implementing the methods according to the present application. Therefore, the present application also covers a recording medium storing a program for executing the methods according to the present application.

[0158] Obviously, those skilled in the art should understand that the various modules or steps of the present application described above can be implemented by a general-purpose computing device. They can be concentrated on a single computing device or distributed over a network composed of multiple computing devices. Optionally, they can be implemented by program codes executable by the computing device. Thus, they can be stored in a storage device and executed by the computing device. And in some cases, the steps shown or described can be executed in a sequence different from that here, or they can be separately fabricated into individual integrated circuit modules, or multiple modules or steps among them can be fabricated into a single integrated circuit module for implementation. In this way, the present application is not limited to any specific combination of hardware and software.

[0159] The foregoing is only a preferred embodiment of the present application and is not intended to limit the present application. For those skilled in the art, the present application can have various changes and modifications. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included within the protection scope of the present application.

Claims

1. A method for exploiting heavy oil, characterized in that, Including: Obtaining the horizontal section length information of a horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of vertical steam injection wells; According to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and multiple preset alternative production well section height difference parameters, respectively calculating the corresponding alternative production well section length parameters and recovery rates for each alternative production well section height difference parameter; Determining the length parameter of the production well section according to the recovery rates corresponding to each alternative production well section length parameter and the spacing information of the vertical steam injection wells, and dividing the horizontal production well into multiple production well sections based on the length parameter of the production well section; Real-time monitoring the height parameter of the steam cavity, and controlling the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameter of the steam cavity; The step of, according to the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and multiple preset alternative production well section height difference parameters, respectively calculating the corresponding alternative production well section length parameters and recovery rates for each alternative production well section height difference parameter, includes: Based on multiple preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction, respectively obtaining multiple alternative production well section length parameters; Respectively calculating the height parameters of the steam cavity corresponding to each of the alternative production well section length parameters according to each of the alternative production well section length parameters; Respectively calculating the horizontal advance distance parameters of each of the steam cavities according to the height parameters of the steam cavity corresponding to each of the alternative production well section length parameters; Respectively calculating the recovery rates corresponding to each of the alternative production well section length parameters according to the height parameters of the steam cavity corresponding to each of the alternative production well section length parameters and the horizontal advance distance parameters.

2. The method according to claim 1, wherein Before the step of real-time monitoring the height parameter of the steam cavity and controlling the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameter of the steam cavity, the method further includes: Performing preheating treatment on the horizontal production well and the vertical steam injection wells, and real-time monitoring the formation pressure parameter and the inter-well temperature parameter; If the formation pressure parameter reaches the preset formation pressure parameter threshold and the inter-well temperature parameter reaches the preset inter-well temperature parameter threshold, then controlling the first production well section among the multiple production well sections to enter the heavy oil exploitation stage.

3. The method according to claim 1, wherein The step of real-time monitoring the height parameter of the steam cavity and controlling the multiple production well sections to sequentially carry out heavy oil exploitation according to the height parameter of the steam cavity specifically includes: Real-time monitoring the height parameter of the steam cavity; If the height parameter of the steam cavity reaches the preset height parameter threshold, then controlling the next production well section to enter the heavy oil exploitation stage.

4. The method according to claim 3, wherein The step of real-time monitoring the height parameter of the steam cavity specifically includes: Real-time obtaining the temperature and pressure data of the steam cavity; Calculating the real-time height parameter of the steam cavity based on the temperature and pressure data.

5. The method according to any one of claims 1-4, characterized in that, The method further includes: Monitor and adjust the height parameter of the vapor-liquid interface above the horizontal production well in real time so that the height parameter of the vapor-liquid interface is within a preset vapor-liquid interface height parameter threshold.

6. An extraction system for heavy oil, characterized in that, Including: An acquisition module for acquiring the horizontal section length information of the horizontal production well, the included angle information between the horizontal section of the horizontal production well and the horizontal direction, and the spacing information of the vertical steam injection wells; A calculation module for obtaining multiple alternative production well section length parameters respectively based on multiple preset alternative production well section height difference parameters, the horizontal section length information of the horizontal production well, and the included angle information between the horizontal section of the horizontal production well and the horizontal direction; The calculation module is further configured to calculate the height parameter of the steam cavity corresponding to each of the alternative production well section length parameters respectively according to each of the alternative production well section length parameters; The calculation module is further configured to calculate the horizontal advance distance parameter of each of the steam cavities respectively according to the height parameter of the steam cavity corresponding to each of the alternative production well section length parameters; The calculation module is further configured to calculate the recovery factor corresponding to each of the alternative production well section length parameters respectively according to the height parameter of the steam cavity corresponding to each of the alternative production well section length parameters and the horizontal advance distance parameter; A division module for determining the length parameter of the production well section according to the recovery factor corresponding to each of the alternative production well section length parameters and the spacing information of the vertical steam injection wells, and dividing the horizontal production well into multiple production well sections based on the length parameter of the production well section; An oil production module for monitoring the height parameter of the steam cavity in real time and controlling the heavy oil production of the multiple production well sections in sequence according to the height parameter of the steam cavity.

7. A storage medium storing at least one executable instruction, characterized in that, The executable instruction causes the processor to perform the operations corresponding to the heavy oil production method according to any one of claims 1-5.

8. A terminal, comprising: A processor, a memory, a communication interface, and a communication bus, and the processor, the memory, and the communication interface complete communication with each other through the communication bus; The memory is used to store at least one executable instruction, and is characterized in that the executable instruction causes the processor to perform the operations corresponding to the heavy oil production method according to any one of claims 1-5.

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