A method and system for designing gas injection volume in heavy oil natural gas huff and puff

Abstract

The present application relates to the technical field of oil and gas field development, and particularly relates to a heavy oil natural gas huff and puff gas injection amount design method and system. The heavy oil natural gas huff and puff gas injection amount design method comprises the following steps: determining required reservoir parameters, including reservoir porosity, permeability, oil saturation, and oil layer thickness parameters; determining oil product physical property data parameters, including crude oil saturated dissolved gas oil ratio and crude oil density parameters under reservoir conditions; determining engineering parameters, including longitudinal action radius, transverse action radius, and effective treatment coefficient parameters; determining an adaptive model according to the drilling type; and calculating the natural gas huff and puff gas injection amount based on the required reservoir parameters, the oil product physical property data parameters, and the engineering parameters, and according to the adaptive model. The present application solves the problem of the absence of gas injection amount calculation engineering algorithm for heavy oil natural gas huff and puff.

Description

Technical Field

[0001] This invention relates to the field of oil and gas field development technology, specifically to a method and system for designing the injection volume of heavy oil and natural gas. Background Technology

[0002] Currently, the heavy oil reservoirs in Dagang are mainly sandstone reservoirs. Water-drive development is hampered by the large difference in oil-water mobility ratios, resulting in low oil displacement efficiency and ultimately low recovery rates. This is especially true for ultra-low mobility reservoirs below 10, where mobility significantly impacts oil displacement efficiency, making water control and oil enhancement difficult, as well as improving recovery rates challenging in water-drive cold production. According to China's heavy oil classification and recommended development technologies, heavy oil with a viscosity greater than 100 mPa·s is best developed using steam injection followed by steam drive. However, Dagang's heavy oil reservoirs were initially developed using water drive, employing conventional well completion methods, which are insufficient to meet wellbore requirements. Furthermore, some reservoirs exceed the current limits for thermal recovery, resulting in significant heat loss along the wellbore, making current technologies inadequate for development requirements. Natural gas is widely used in heavy oil development due to its good compatibility with crude oil, strong reservoir adaptability, and lack of corrosive damage to gathering and transportation systems. Heavy oil injection is the primary method, but optimizing the injection volume remains a challenge, as there are currently no established methods in the industry. The injection volume is crucial for gas source preparation, performance prediction, and economic benefit evaluation.

[0003] Patent CN113356806B discloses a method, apparatus, and electronic device for adjusting gas injection volume based on gas-driven sweep efficiency. The method includes: obtaining tracer well group sweep efficiency parameters, nitrogen well group sweep efficiency volume, well group area, and the height of the shallowest producing layer; obtaining the gas-driven longitudinal sweep efficiency coefficient based on the tracer well group sweep efficiency parameters, nitrogen well group sweep efficiency volume, and the height of the shallowest producing layer; obtaining the gas-driven planar sweep efficiency coefficient based on the tracer well group sweep efficiency parameters, nitrogen well group sweep efficiency volume, and well group area; multiplying the gas-driven longitudinal sweep efficiency coefficient and the gas-driven planar sweep efficiency coefficient to obtain the gas-driven sweep efficiency coefficient; and adjusting the gas injection volume of the injection well based on the gas-driven sweep efficiency coefficient. However, this method only considers the sweep efficiency coefficient, and the sweep efficiency coefficient needs to be determined based on tracer results, but the tracer testing process is time-consuming and expensive, making it unreliable for reference.

[0004] The invention patent application with publication number CN118148582A discloses a method for improving the recovery rate of single-well gas injection and huff-and-puff in fault-controlled reservoirs. The well-reservoir relationship gas injection and huff-and-puff model is only applicable to fault-controlled fractured-vuggy reservoirs and is not applicable to sandstone reservoirs.

[0005] Patent CN103470233B discloses a natural gas huff-and-puff production system and method for heavy oil reservoirs. The method includes: drilling a well in the target area of ​​the reservoir, penetrating the formation, oil layer, separator, and natural gas layer from top to bottom, connecting the oil and gas layers in the wellbore, and perforating both layers. The wellbore length is selected, and a flow meter, pressure gauge, and flow control valve are installed. A production string and cable are run in series, connecting the first tubing, pump, wellbore, packer, and second tubing, with the cable transmitting signals. The packer is set. A Christmas tree and pumping unit are installed. The well is shut in, and the flow control valve is opened to allow natural gas to flow into the oil layer. The flow control valve is closed, and the well is then shut in for a designed shut-in time. After the designed shut-in time, the well is opened for production. This method only describes the natural gas huff-and-puff process and does not provide a specific algorithm for calculating the natural gas usage.

[0006] In summary, there is currently no specific algorithm suitable for the natural gas injection rate in sandstone reservoirs. Therefore, it is necessary to establish a design method for the injection rate of natural gas in heavy oil reservoirs. Summary of the Invention

[0007] The proposed method for designing the injection volume of heavy oil and natural gas huff and puff in this invention calculates the required injection volume of heavy oil and natural gas huff and puff wells based on parameters such as reservoir parameters, oil physical property data parameters, and well type, through engineering calculation methods. This solves the problem of the lack of engineering algorithms for calculating the injection volume of heavy oil and natural gas huff and puff in sandstone reservoirs.

[0008] The first aspect of this invention provides a method for designing the injection volume of heavy oil natural gas, including the following steps: S1. Determine the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. S2, determine the physical property data parameters of oil products, including the saturated dissolved gas-oil ratio of crude oil and the density parameters of crude oil under reservoir conditions; S3, determine the engineering parameters, including longitudinal radius of action, transverse radius of action, and effective treatment coefficient parameters; S4, determine the appropriate model based on the drilling type; S5 calculates the natural gas injection / huffing volume based on the required reservoir parameters, oil product physical property data parameters, and engineering parameters, and according to the adaptation model.

[0009] In some embodiments, the adaptation model includes an elliptical cylinder model and an ellipsoidal model, and the drilling type includes horizontal wells and directional wells. Step S4, determining the adaptation model according to the drilling type includes: when the drilling type is a horizontal well, the adaptation model is determined to be an elliptical cylinder model; when the drilling type is a directional well, the adaptation model is determined to be an ellipsoidal model.

[0010] In some embodiments, step S5, based on the required reservoir parameters, oil product property data parameters, and engineering parameters, and according to the adaptation model, calculates the natural gas injection / huffing volume, including: When the adaptation model is an elliptical cylindrical model, the natural gas injection volume is calculated using the following formula: V=P L πabLφS O pR s In the formula V This refers to the amount of natural gas injected during the throughput process. P L For effective processing coefficients; a The longitudinal radius of action; b The lateral radius of action; L The length of the horizontal segment; f This represents the percentage of reservoir porosity. S O It represents the percentage of oil saturation. r The density of crude oil under reservoir conditions; R S The saturated dissolved gas-oil ratio of crude oil; When the adaptation model is an ellipsoidal model, the natural gas injection volume is calculated using the following formula: V=4P L pub 2 φS O pR S / 3； In the formula P L For effective processing coefficients; a The longitudinal radius of action; b The radius of action is the lateral direction. f This represents the percentage of reservoir porosity. S O It represents the percentage of oil saturation. r The density of crude oil under reservoir conditions; R S The saturated dissolved gas-oil ratio of crude oil.

[0011] In some embodiments, step S3, determining engineering parameters, includes: The longitudinal radius of action is determined based on the oil layer thickness. The lateral radius of action is determined based on the longitudinal radius of action and the permeability.

[0012] In some embodiments, the longitudinal radius of action is set to half the thickness of the oil layer, and the transverse radius of action is set to 5 to 10 times the longitudinal radius of action.

[0013] In some embodiments, if the reservoir is a low-permeability reservoir, the lateral action radius is set to 5 times the longitudinal action radius; if the reservoir is a high-permeability reservoir, the lateral action radius is set to 10 times the longitudinal action radius.

[0014] In some embodiments, the effective processing coefficient ranges from 0.1 to 0.2.

[0015] In some embodiments, if the reservoir is a low-permeability reservoir, the effective treatment coefficient is 0.1; if the reservoir is a high-permeability reservoir, the effective treatment coefficient is 0.2.

[0016] A second aspect of the present invention provides a heavy oil natural gas injection volume design system, comprising: The reservoir parameter determination module is configured to obtain the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. The oil product physical property data parameter determination module is configured to acquire oil product physical property data parameters, including the crude oil saturated dissolved gas-oil ratio and the crude oil density under reservoir conditions. The engineering parameter determination module is configured to determine engineering parameters, including longitudinal action radius, transverse action radius, and effective treatment coefficient. The model selection module is configured to select the appropriate model based on the drilling type. The natural gas consumption calculation module is configured to calculate the natural gas throughput and injection volume based on the data provided by the above modules and the selected adaptation model.

[0017] In some embodiments, the heavy oil and natural gas injection capacity design system further includes: The data processing and analysis module is configured to process and analyze all input data, create data visualizations, and generate reports. The user interface module is configured to provide a user-friendly interface that allows users to input necessary parameters, view calculation results, and adjust settings.

[0018] The beneficial effects of this invention are as follows: Based on reservoir parameters, oil product physical property data parameters and engineering parameters, this application calculates the required natural gas injection volume for heavy oil natural gas huff and puff wells through engineering calculation methods. The injection volume has guiding significance for gas source preparation, effect prediction and economic benefit evaluation. It has strong scientific and practical value and has good application prospects and promotion value. Attached Figure Description

[0019] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other embodiments can be obtained based on these drawings without creative effort.

[0020] Figure 1 This is a schematic diagram of an elliptical cylindrical model for calculating natural gas throughput and injection volume corresponding to a horizontal well, provided in one embodiment of the present invention. Figure 2 This is a schematic diagram of an ellipsoidal model for calculating the gas throughput and injection volume corresponding to a directional well, provided in one embodiment of the present invention. Detailed Implementation

[0021] To make the objectives, technical solutions, and advantages of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to specific examples and the accompanying drawings.

[0022] It should be noted that all uses of "first" and "second" in the embodiments of the present invention are for the purpose of distinguishing two entities or parameters with the same name but different names. It is clear that "first" and "second" are only for the convenience of expression and should not be construed as limiting the embodiments of the present invention. Subsequent embodiments will not explain this in detail.

[0023] The first aspect of this invention provides a method for designing the injection volume of heavy oil natural gas, comprising the following steps: S1. Determine the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. Specifically, the pore space of the rock can be assessed through coring analysis or geophysical logging data; the ability of the rock to allow fluid passage can be determined through laboratory tests or field injection tests; the oil content in the rock can be estimated through methods such as resistivity logging or nuclear magnetic resonance logging; and the vertical thickness of the reservoir can be determined through seismic exploration or drilling data.

[0024] S2. Determine the physical property parameters of the oil product, including the saturated dissolved gas-oil ratio and the crude oil density under reservoir conditions. Specifically, measure the ratio of the volume of dissolved natural gas in the crude oil under saturated pressure to the volume of degassed crude oil at the surface in the laboratory; and determine the density of the crude oil using equations of state or experimental data based on the temperature and pressure conditions of the reservoir.

[0025] S3. Determine the engineering parameters, including: longitudinal radius of action, lateral radius of action, and effective treatment coefficient. Specifically, determine the range of influence of longitudinal and lateral gas injection based on the geological characteristics of the reservoir and the design of the injection well. In particular, the effective treatment coefficient is an empirical value, usually determined based on historical data and case studies of similar reservoirs.

[0026] S4, determine the appropriate model based on the drilling type; S5 calculates the natural gas injection / huffing volume based on the required reservoir parameters, oil product physical property data parameters, and engineering parameters, and according to the adaptation model.

[0027] Compared with existing technologies, this invention calculates the required natural gas injection volume for heavy oil and natural gas huff and puff wells based on reservoir parameters, oil physical property data parameters, and engineering parameters through engineering calculation methods. The injection volume is of guiding significance for gas source preparation, effect prediction, and economic benefit evaluation. It has strong scientific and practical value and has good application prospects and promotion value.

[0028] In some embodiments, the adaptation model includes an elliptical cylinder model and an ellipsoidal model, and the drilling type includes horizontal wells and directional wells. Step S4 involves determining the adaptation model based on the drilling type, including: when the drilling type is a horizontal well, the adaptation model is determined to be an elliptical cylinder model; when the drilling type is a directional well, the adaptation model is determined to be an ellipsoidal model. Specifically, horizontal wells mainly extend laterally in the reservoir, and their wellbore trajectory has a large contact area with the oil layer. The engineering parameters of horizontal wells, such as the longitudinal radius of influence and the lateral radius of influence, are consistent with the parameter settings of the elliptical cylinder model. Therefore, the elliptical cylinder model is more suitable for describing its influence range and can better reflect the sweep efficiency and oil and gas co-production effect of horizontal wells in the reservoir. Directional wells not only extend laterally but also have a certain penetration depth in the vertical direction. The engineering parameters of directional wells, such as the longitudinal radius of influence, the lateral radius of influence, and the ratio between them, are matched with the parameter settings of the ellipsoidal model. Therefore, the ellipsoidal model can better describe the fluid flow and influence range in three-dimensional space, thereby more accurately calculating the gas injection volume.

[0029] In some embodiments, step S5, based on the required reservoir parameters, oil product property data parameters, and engineering parameters, and according to the adaptation model, calculates the natural gas injection / huffing volume, including: When the adaptation model is an elliptical cylindrical model, the natural gas injection volume is calculated using the following formula: V=P L πabLφS O pR s Formula (1); In the formula VThis refers to the natural gas injection / outflow volume, measured in m³. P L The effective processing coefficient is 0.1 to 0.2, and is dimensionless. a The longitudinal radius of action is in meters. b The lateral radius of action is expressed in meters (m). L The horizontal segment length is expressed in meters (m). f Percentage of reservoir porosity, dimensionless; S O The percentage of oil saturation is dimensionless. r The density of crude oil under reservoir conditions is expressed in t / m³. R S The saturated dissolved gas-oil ratio is expressed in m³ / t.

[0030] This calculation formula can be used to calculate the required gas injection volume for horizontal wells.

[0031] When the adaptation model is an ellipsoidal model, the natural gas injection volume is calculated using the following formula: V=4P L pub 2 φS O pR S / 3 Formula (2); In the formula P L The effective processing coefficient is 0.1 to 0.2, and is dimensionless. a The longitudinal radius of action is in meters. b The lateral radius of action is expressed in meters (m). f Percentage of reservoir porosity, dimensionless; S O The percentage of oil saturation is dimensionless. r The density of crude oil under reservoir conditions is expressed in t / m³. R S The saturated dissolved gas-oil ratio is expressed in m³ / t.

[0032] This calculation formula can be used to calculate the required directional well gas injection volume.

[0033] In some embodiments, such as Figure 1 and Figure 2 As shown, in step S3, the engineering parameters are determined, including: determining the longitudinal radius of action based on the oil layer thickness; and determining the lateral radius of action based on the longitudinal radius of action and the permeability.

[0034] In some embodiments, the longitudinal radius of actiona Set to half the oil layer thickness H, lateral radius of action b Set as longitudinal radius of action a 5 to 10 times that. By increasing the lateral radius of action. b Set as the longitudinal radius of action a A ratio 5 to 10 times that of gas injection helps to expand the influence range of gas injection and improve sweep efficiency. For reservoirs with different permeability, the ratio of these two radii can be adjusted to adapt to different geological conditions, promote the formation of foam oil, and further improve the fluidity of crude oil.

[0035] In some embodiments, in step S3, if the reservoir is a low-permeability reservoir, the lateral radius of action is... b Set as longitudinal radius of action a Five times; if the reservoir is a high-permeability reservoir, then the lateral radius of action is... b Set as longitudinal radius of action a Ten times that of other reservoirs. For reservoirs with low permeability, due to the greater flow resistance of fluids in the formation, a larger lateral radius is required to ensure that the injected natural gas can effectively cover a wider area. In this case, the lateral radius... b Set as longitudinal radius of action a Five times the lateral radius of influence, to increase the affected area and improve extraction efficiency. For reservoirs with high permeability, fluid flow is smoother in the formation, therefore the lateral radius of influence is larger. b It can be relatively small. In this case, the lateral radius of action b Set as longitudinal radius of action a Ten times the size of the original size, to adapt to the geological characteristics of high-permeability reservoirs while maintaining the accuracy of gas injection calculations. This is achieved by adjusting the lateral radius of action. b With longitudinal radius of action a The proportion of permeability can be optimized based on the permeability characteristics of different reservoirs to determine the gas injection scheme. Specifically, low-permeability reservoirs have relatively low permeability, typically less than 50 × 10⁻³ μm² (millidarcy). In the industry, reservoirs with permeability of 0.0001–0.05 square micrometers are generally referred to as low-permeability oil layers. High-permeability reservoirs have relatively high permeability, generally greater than 500 × 10⁻³ μm² (millidarcy).

[0036] In some embodiments, in step S3, the effective treatment coefficient ranges from 0.1 to 0.2, and the value of the effective treatment coefficient is positively correlated with the reservoir permeability. Setting the effective treatment coefficient ensures that the injected natural gas can more effectively cover the reservoir area, thereby improving sweep efficiency. By adjusting the effective treatment coefficient, the gas injection scheme can be optimized, resulting in a more uniform distribution of natural gas in the reservoir and improving the oil and gas co-production effect.

[0037] In some embodiments, in step S3, if the reservoir is a low-permeability reservoir, the effective treatment factor is 0.1; if the reservoir is a high-permeability reservoir, the effective treatment factor is 0.2. Due to the poor reservoir properties in low-permeability reservoirs, the flow resistance of fluids in the formation is high, resulting in low single-well productivity and poor production stability. Therefore, a smaller effective treatment factor is needed to ensure that the injected natural gas can more effectively cover a wider area. For high-permeability reservoirs, fluid flow in the formation is relatively easy, resulting in high single-well productivity and good production stability. Therefore, a larger effective treatment factor can be used to improve gas injection efficiency.

[0038] A second aspect of the present invention provides a heavy oil natural gas injection volume design system, comprising: The reservoir parameter determination module is configured to obtain the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. These parameters are the basis for subsequent calculations. The oil product physical property data parameter determination module is configured to acquire oil product physical property data parameters, including the crude oil saturated dissolved gas-oil ratio and the crude oil density under reservoir conditions, which are very important for assessing the fluidity and recoverability of crude oil. The engineering parameter determination module is configured to determine engineering parameters, including longitudinal radius of action, lateral radius of action, and effective treatment coefficient. These parameters directly affect the design of the gas injection volume and need to be optimized according to specific engineering conditions and objectives. The adaptation model selection module is configured to select an adaptation model (such as an elliptical cylinder model or an ellipsoidal model) based on the drilling type (such as a horizontal well or a directional well) to calculate the gas injection volume; The natural gas consumption calculation module is configured to calculate the natural gas injection volume based on the data provided by the above modules and the selected model. This is the core output of the entire system and is directly related to the implementation of the gas injection operation.

[0039] In some embodiments, the heavy oil and natural gas injection capacity design system further includes: The data processing and analysis module is configured to process and analyze all input data, ensuring data accuracy and consistency. It can also create data visualizations and generate reports to support the decision-making process. The user interface module is configured to provide a user-friendly interface that allows users to input necessary parameters, view calculation results, and adjust settings, making the system easy to use even for non-professionals.

[0040] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0041] An embodiment of the present invention provides a method for designing the injection volume of heavy oil natural gas huff and puff, taking a heavy oil huff and puff well in the X test area as an example, to illustrate the specific implementation steps of the present invention: Step 1: Determine the required reservoir parameters. The reservoir where this well is located has a porosity of 13.35%, a permeability of 132.7 mD, an oil saturation of 62.37%, and an oil layer thickness of 18.3 m.

[0042] Step 2: Determine the physical property data parameters of the oil. The saturated dissolved gas-oil ratio of the crude oil in this well is 201 m³ / t, and the crude oil density under reservoir conditions is 0.918 t / m³.

[0043] Step 3: Determine the engineering parameters. The longitudinal radius of the well is half the thickness of the oil layer H, i.e., 9.15m; the permeability of the well is 132.7mD, which is a medium permeability reservoir. Therefore, the lateral radius of the well is taken as 8 times the longitudinal radius of the well, i.e., 73.2m; the effective treatment coefficient is taken as 0.15.

[0044] Step 4: Determine the appropriate model based on the well type and calculate the natural gas injection / injection volume. This well is a directional well; using formula (2), i.e., the ellipsoidal model, the required natural gas consumption is calculated to be 47 × 10⁻⁶. 4 m³, the method took a total of 0.5 days.

[0045] To verify the scientific validity and practicality of the calculated natural gas injection rate, a numerical simulation was conducted. Based on the reservoir geological model and natural gas throughput numerical simulation, the entire process took 8 days. The optimal natural gas injection rate for this well was calculated to be (42~51)×10. 4 The simulated oil increase was 981-1120 tons per cubic meter. Using this method, the natural gas consumption of a heavy oil huff and puff well in test area X was calculated, and a field test was conducted. The test well ultimately achieved an oil increase of 1055 tons, demonstrating a good oil increase effect. Therefore, this method is feasible and effectively guides the calculation of gas injection volume in heavy oil and natural gas huff and puff wells, with significant advantages such as short calculation time and high accuracy.

[0046] In conclusion, the method for designing the injection volume of heavy oil and natural gas is scientifically sound and practical, and has good application prospects and promotion value.

[0047] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0048] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are relatively specific and detailed, they should not be construed as limiting the scope of the invention patent. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these all fall within the protection scope of this application. Therefore, the protection scope of this patent application should be determined by the appended claims.

Claims

1. A method for designing the injection volume of heavy oil and natural gas, characterized in that, Includes the following steps: S1, determine the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. S2, determine the oil product physical property data parameters, including the crude oil saturated dissolved gas-oil ratio and crude oil density parameters under reservoir conditions; S3, determine the engineering parameters, including longitudinal radius of action, transverse radius of action, and effective processing coefficient parameters; S4, determine the appropriate model based on the drilling type; S5 calculates the natural gas injection / huffing volume based on the required reservoir parameters, oil product physical property data parameters, and engineering parameters, and according to the adaptation model.

2. The method for designing heavy oil and natural gas injection volume according to claim 1, characterized in that, The adaptation models include elliptical cylinder models and ellipsoidal models, and the drilling types include horizontal wells and directional wells. Step S4: Determine the adaptation model based on the drilling type, including: when the drilling type is a horizontal well, the adaptation model is determined to be an elliptical cylinder model; when the drilling type is a directional well, the adaptation model is determined to be an ellipsoidal model.

3. The method for designing the injection volume of heavy oil and natural gas according to claim 2, characterized in that, Step S5 involves calculating the natural gas injection / huffing rate based on the required reservoir parameters, oil product property data parameters, and engineering parameters, according to the adaptation model. This includes: When the adaptation model is an elliptical cylindrical model, the natural gas injection volume is calculated using the following formula: V=P L πabLφS O ρR s In the formula V This refers to the amount of natural gas injected during the throughput process. P L For effective processing coefficients; a The longitudinal radius of action; b The radius of action is the lateral direction. L The length of the horizontal segment; φ This represents the percentage of reservoir porosity. S O It represents the percentage of oil saturation. ρ The density of crude oil under reservoir conditions; R S The saturated dissolved gas-oil ratio of crude oil; When the adaptation model is an ellipsoidal model, the natural gas injection volume is calculated using the following formula: V=4P L πab 2 φS O ρR S / 3； In the formula P L For effective processing coefficients; a The longitudinal radius of action; b The radius of action is the lateral direction. φ This represents the percentage of reservoir porosity. S O It represents the percentage of oil saturation. ρ The density of crude oil under reservoir conditions; R S The saturated dissolved gas-oil ratio of crude oil.

4. The method for designing the injection volume of heavy oil and natural gas according to claim 3, characterized in that, Step S3, determine the engineering parameters, including: The longitudinal radius of action is determined based on the oil layer thickness; The lateral radius of action is determined based on the longitudinal radius of action and the permeability.

5. The method for designing the injection volume of heavy oil and natural gas according to claim 4, characterized in that, The longitudinal radius of action is set to half the thickness of the oil layer, and the transverse radius of action is set to 5 to 10 times the longitudinal radius of action.

6. The method for designing the injection volume of heavy oil and natural gas according to claim 5, characterized in that, If the reservoir is a low-permeability reservoir, the lateral radius of action is set to 5 times the longitudinal radius of action; if the reservoir is a high-permeability reservoir, the lateral radius of action is set to 10 times the longitudinal radius of action.

7. The method for designing the injection volume of heavy oil and natural gas according to claim 3, characterized in that, The effective processing coefficient ranges from 0.1 to 0.

2.

8. The method for designing the injection volume of heavy oil and natural gas according to claim 7, characterized in that, If the reservoir is a low-permeability reservoir, the effective treatment coefficient is 0.1; if the reservoir is a high-permeability reservoir, the effective treatment coefficient is 0.

2.

9. A heavy oil-natural gas injection volume design system, characterized in that, include: The reservoir parameter determination module is configured to obtain the required reservoir parameters, including reservoir porosity, permeability, oil saturation, and reservoir thickness. The oil product physical property data parameter determination module is configured to acquire oil product physical property data parameters, including the crude oil saturated dissolved gas-oil ratio and the crude oil density under reservoir conditions. The engineering parameter determination module is configured to determine engineering parameters, including longitudinal action radius, transverse action radius, and effective processing coefficient. The model selection module is configured to select the appropriate model based on the drilling type. The natural gas consumption calculation module is configured to calculate the natural gas throughput and injection volume based on the data provided by the above modules and the selected adaptation model.

10. The heavy oil and natural gas injection volume design system according to claim 9, characterized in that, Also includes: The data processing and analysis module is configured to process and analyze all input data, create data visualizations, and generate reports. The user interface module is configured to provide a user-friendly interface that allows users to input necessary parameters, view calculation results, and adjust settings.

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