Carbonate oil and gas reservoir production control method and device

Abstract

The present application provides a method and device for controlling the exploitation of a carbonate oil and gas reservoir. The method includes: determining the target number of test points in the reservoir according to the preset height difference between adjacent test points in the reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; obtaining the producing height of the reservoir according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference; and controlling the depth of the drill pipe drilling in the production well according to the producing height of the reservoir. Therefore, the producing height of the carbonate oil and gas reservoir can be accurately determined, and then the depth of the drill pipe drilling in the production well can be controlled to improve the production capacity of the production well.

Description

Technical Field

[0001] The present application relates to the field of geological exploration technology, and in particular to a method and device for controlling the exploitation of carbonate oil and gas reservoirs. Background Art

[0002] With the rapid development of the petroleum industry, a large number of carbonate oil and gas reservoirs have been discovered. Carbonate oil and gas reservoirs have the characteristics of complex geological conditions, multiple reservoir types, strong heterogeneity, and complex and diverse fluid types and distribution. Carbonate reservoirs have become an important field for oil and gas exploration and development. The reservoir production height of carbonate oil and gas reservoirs is a very important parameter to measure the development effect and development potential of carbonate oil and gas reservoirs. It is used to evaluate the enrichment of oil and gas in the entire block of carbonate oil and gas reservoirs vertically, adjust the development method, guide the deployment of new wells to drill the target layer thickness, and then control the depth of drill pipe drilling in production wells to improve the production capacity of production wells. Therefore, it is urgent to determine the production height of carbonate oil and gas reservoirs. Summary of the invention

[0003] The present application provides a carbonate oil and gas reservoir production control method and device to accurately determine the production height of the carbonate oil and gas reservoir, thereby controlling the drilling depth of the drill pipe in the production well and improving the production capacity of the production well.

[0004] In a first aspect, the present application provides a method for controlling the production of a carbonate oil and gas reservoir, comprising:

[0005] Obtaining the preset height difference between adjacent test points in a carbonate oil and gas reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well;

[0006] Determine the target number of test points in the reservoir based on the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir;

[0007] According to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, the producing height of the reservoir is obtained, and the producing height is the height from the bottom of the production well to the position where the fluid in the reservoir does not flow;

[0008] According to the utilization height of the reservoir, the depth of the drill pipe drilling in the production well is controlled.

[0009] Optionally, a target number of test points in the reservoir is determined based on a preset height difference, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in a carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of the first test point in the reservoir, including:

[0010] Obtain the first corresponding relationship between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity;

[0011] According to the first corresponding relationship, a second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity is obtained;

[0012] Obtaining a third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target quantity;

[0013] The target quantity is determined according to the second corresponding relationship and the third corresponding relationship.

[0014] Optionally, the first corresponding relationship is expressed by the following formula 1:

[0015] G 流n =G 流1 -(n-1)×ΔG 流 Formula 1

[0016] Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets.

[0017] Optionally, the second corresponding relationship is expressed by the following formula 2:

[0018]

[0019] Among them, T 流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

[0020] Optionally, the third corresponding relationship is expressed by the following formula 3:

[0021]

[0022] Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

[0023] Optionally, determining the target quantity according to the second corresponding relationship and the third corresponding relationship includes:

[0024] According to formula 2 and formula 3, formula 4 is obtained;

[0025] According to formula 4, the target quantity is obtained;

[0026] Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

[0027] Optionally, the producing height of the reservoir is obtained according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, including:

[0028] According to the following formula 5, the mobilization height is obtained:

[0029] h=n×ΔH-(HH 1 ) Formula 5

[0030] Where h represents the producing height of the reservoir, H 1 represents the depth of the first test point, and H represents the depth of the production well.

[0031] In a second aspect, the present application provides a production control device for a carbonate oil and gas reservoir, comprising:

[0032] An acquisition module is used to acquire a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in the carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of a first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and other test points are located in the reservoir below the production well;

[0033] A determination module, for determining a target number of test points in the reservoir according to a preset height difference, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in a carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of a first test point in the reservoir;

[0034] A processing module, for obtaining a producing height of the reservoir according to a target number of test points in the reservoir, a depth of a first test point, a depth of a production well, and a preset height difference, wherein the producing height is a height from a bottom of the production well to a position where fluid does not flow in the reservoir;

[0035] The control module is used to control the depth of drilling by the drill pipe in the production well according to the production height of the reservoir.

[0036] Optionally, determine the module, specifically for:

[0037] Obtain the first corresponding relationship between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity;

[0038] According to the first corresponding relationship, a second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity is obtained;

[0039] Obtaining a third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target quantity;

[0040] The target quantity is determined according to the second corresponding relationship and the third corresponding relationship.

[0041] Optionally, the first corresponding relationship is expressed by the following formula 1:

[0042] G 流n =G 流1 -(n-1)×ΔG 流 Formula 1

[0043] Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets.

[0044] Optionally, the second corresponding relationship is expressed by the following formula 2:

[0045]

[0046] Among them, T 流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

[0047] Optionally, the third corresponding relationship is expressed by the following formula 3:

[0048]

[0049] Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

[0050] Optionally, determine the module, specifically for:

[0051] According to formula 2 and formula 3, formula 4 is obtained;

[0052] According to formula 4, the target quantity is obtained;

[0053] Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

[0054] Optional, processing module, specifically used for:

[0055] According to the following formula 5, the mobilization height is obtained:

[0056] h=n×ΔH-(HH 1 ) Formula 5

[0057] Where h represents the producing height of the reservoir, H 1 represents the depth of the first test point, and H represents the depth of the production well.

[0058] In a third aspect, the present application provides a carbonate oil and gas reservoir production control device, comprising: a memory and a processor;

[0059] The memory is used to store program instructions;

[0060] The processor is used to call the program instructions in the memory to execute the production control method for carbonate oil and gas reservoirs as described in the first aspect of the present application.

[0061] In a fourth aspect, the present application provides a computer-readable storage medium, in which computer program instructions are stored. When the computer program instructions are executed, the carbonate oil and gas reservoir production control method of the first aspect of the present application is implemented.

[0062] The present application provides a carbonate oil and gas reservoir production control method and device, which obtains a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, the depth of a production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in a production well in a carbonate oil and gas reservoir, at least one test point includes a first test point, and the other test points are located in the reservoir below the production well; according to the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir, the target number of test points in the reservoir is determined; according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, the producing height of the reservoir is obtained, the producing height being the height from the bottom of the production well to the position where the fluid does not flow in the reservoir; according to the producing height of the reservoir, the depth of the drill pipe drilling in the production well is controlled. Through the above method, the utilization height of carbonate oil and gas reservoirs can be accurately determined. When producing wells, the depth of drill pipe drilling in the production wells can be controlled to improve the production capacity of the production wells. At the same time, it provides technical support for evaluating the vertical oil and gas enrichment degree of the entire block of carbonate oil and gas reservoirs; provides a basis for the formulation of a reasonable working system for a single well, so as to make full use of the formation energy and increase the water-free oil production period of a single well; and can also provide a reference for the prediction of the oil-water interface and guide the deployment of new wells to drill the target layer thickness to improve the utilization of reserves. BRIEF DESCRIPTION OF THE DRAWINGS

[0063] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, a brief introduction will be given below to the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative labor.

[0064] Figure 1 A schematic diagram of flow temperature and static temperature changing with vertical depth provided in an embodiment of the present application;

[0065] Figure 2 A flow chart of a method for controlling the production of a carbonate oil and gas reservoir provided in one embodiment of the present application;

[0066] Figure 3 A schematic diagram of a method for determining the producing height of a carbonate oil and gas reservoir provided in an embodiment of the present application;

[0067] Figure 4 A schematic diagram of static temperature gradient fitting provided in one embodiment of the present application;

[0068] Figure 5 A flow chart of a carbonate oil and gas reservoir production control method provided in another embodiment of the present application;

[0069] Figure 6 A schematic diagram of the structure of a carbonate oil and gas reservoir production control device provided in one embodiment of the present application;

[0070] Figure 7 A schematic diagram of the structure of a carbonate oil and gas reservoir production control device provided in another embodiment of the present application;

[0071] Figure 8 A schematic structural diagram of a carbonate oil and gas reservoir production control device provided in another embodiment of the present application. DETAILED DESCRIPTION

[0072] In order to make the purpose, technical solution and advantages of the embodiments of the present application clearer, the technical solution in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0073] With the rapid development of the petroleum industry, a large number of carbonate oil and gas reservoirs have been discovered. Carbonate oil and gas reservoirs have the characteristics of complex geological conditions, multiple reservoir types, strong heterogeneity, and complex and diverse fluid types and distribution. Carbonate reservoirs have become an important field for oil and gas exploration and development. The reservoir production height of carbonate oil and gas reservoirs is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir. It is a very important parameter to measure the development effect and development potential of carbonate oil and gas reservoirs. It is used to evaluate the enrichment of oil and gas in the entire block of carbonate oil and gas reservoirs vertically, adjust the development method, guide the deployment of new wells to drill the target layer thickness, and then control the depth of drill pipe drilling in the production well to improve the production capacity of the production well. For example, the Ordovician carbonate reservoir in the Tahe South Oilfield in the Tabei area of ​​the Tarim Basin is a typical fault-controlled fracture-cavity carbonate reservoir. Oil and gas migrate and accumulate along strike-slip faults, with high filling intensity. The Yijianfang Formation-Yingshan Formation of the Ordovician is oil-bearing as a whole and enriched along the fault zone. The oil column is high, but the vertical connectivity is complex, and it is difficult to determine the production height of the oil well, which brings troubles to the formulation of a reasonable work system and the construction of supporting facilities on the ground. Due to the complexity of the underground fluid movement law and connectivity relationship of carbonate oil and gas reservoirs, it is currently impossible to accurately calculate the production height of a single well reservoir.

[0074] Therefore, the present application provides a method and device for controlling the exploitation of carbonate oil and gas reservoirs. There is a critical point P at the reservoir utilization height of the production well. Below point P, the fluid does not flow, while above point P, the fluid can be mobilized, and the flow temperature at the same vertical depth is higher than the static temperature. As the vertical depth increases, the difference between the flow temperature and the static temperature gradually decreases until point P, when the flow temperature and the static temperature achieve equilibrium and are equal. Figure 1 A schematic diagram of the flow temperature and static temperature changing with vertical depth provided in an embodiment of the present application, such as Figure 1 As shown in the figure, vertical depth refers to the vertical depth. As the vertical depth increases, the flow temperature increases more slowly, while the static temperature increases steadily and reaches a balance at a certain point. At the same time, at the bottom of the well, the flow temperature gradient changes significantly. For every increase in a certain vertical depth, the flow temperature gradient decreases by a certain value, while the static temperature gradient changes slightly. Combining the above two points of understanding, a method for quantitatively calculating the production height of the reservoir of the production well is obtained. When the vertical depth corresponding to the place where the flow temperature and static temperature calculated downward along the vertical depth are equal, that is, the critical point P, the reservoir production height can be obtained. Therefore, the production height of the carbonate oil and gas reservoir can be accurately determined.

[0075] Figure 2 This is a flow chart of a carbonate oil and gas reservoir exploitation control method provided in an embodiment of the present application. The method of this embodiment can be applied to electronic devices, which can be terminal devices, servers, etc. The terminal devices can be, for example, mobile phones, tablet computers, laptop computers, desktop computers, etc. Figure 2 As shown, the method of this embodiment includes:

[0076] S201. Obtain a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, the depth of a production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well.

[0077] In this embodiment, specifically, the flow temperature refers to the temperature tested when the fluid flows when the well is opened for production, and the static temperature is the temperature tested when the fluid does not flow when the well is closed. The temperature gradient refers to the increase in temperature for every 100 meters of depth increase. There are multiple test points in the reservoir in the carbonate oil and gas reservoir, at least one test point is located in the production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well. Figure 3 A schematic diagram of a method for determining the producing height of a carbonate oil and gas reservoir provided in an embodiment of the present application is shown in FIG. Figure 3As shown, it includes a production well 100 and oil 110 in the reservoir below the production well 100, H1 is the depth of the first test point, H2 is the depth of the critical point P, H is the depth of the production well in the carbonate oil and gas reservoir, h is the production height of the reservoir to be determined, there are n test points between H1 and H2, n is the number of targets to be determined, and the height difference between adjacent test points is a preset height difference, for example, 50m.

[0078] The flow temperature gradient change factor of the reservoir is the change of the flow temperature gradient with depth. Specifically, at the bottom of the production well, the flow temperature gradient changes significantly. For each increase in depth, the flow temperature gradient decreases by a certain value. Therefore, according to the flow temperature-vertical depth curve obtained by the professional test instrument of the carbonate oil and gas reservoir, the test data near the bottom of the well near the production well can be selected to analyze the change of the flow temperature gradient with depth, so as to determine a reasonable flow temperature gradient change factor. For example: Table 1 is the test data corresponding to the flow temperature-vertical depth curve near the bottom of the X production well. As shown in Table 1, 7100m is the vertical depth of the maximum test point tested by the professional test instrument. Four points within the depth of the maximum test point (6950m, 7000m, 7050m, 7100m) are selected to analyze the flow temperature gradient change, and the flow temperature gradient change is 0.07℃ / 100m, that is, the flow temperature gradient change factor is 0.07℃ / 100m.

[0079] Table 1 Test data corresponding to the flow temperature-vertical depth curve near the bottom of the X production well

[0080] Vertical depth (m) Flow temperature(℃) Flow temperature gradient (℃ / 100m) 6950 153.60 0.75 7000 153.94 0.69 7050 154.26 0.62 7100 154.53 0.55

[0081] The preset static temperature gradient is the amount of change of the static temperature gradient with depth. Specifically, at the bottom of the production well, the static temperature gradient changes slightly with each increase in depth, and the static temperature gradient can be regarded as a constant. Therefore, according to the static temperature-vertical depth curve obtained by the professional testing instrument of the carbonate oil and gas reservoir, the test data near the bottom of the production well can be selected to fit the static temperature data, thereby determining the preset static temperature gradient. For example: Table 2 shows the test data corresponding to the static temperature-vertical depth curve of the X production well. The test data near the bottom of the production well was selected to fit the static temperature data. Figure 4 A schematic diagram of static temperature gradient fitting provided in an embodiment of the present application, Figure 4 is the fitting information obtained based on the data in Table 2, such as Figure 4 As shown in the figure, the fitting calculation formula used for the preset static temperature gradient is: BHT = 0.0182H + 21.89, where BHT represents static temperature, H is the vertical depth, 0.0182 and 21.89 are fitting constants, and the square of the linear correlation coefficient R (R 2 ) is 0.9998, therefore, the preset static temperature gradient is determined to be 1.82℃ / 100m.

[0082] Table 2 Test data corresponding to the static temperature-vertical depth curve near the bottom of the X production well

[0083] Vertical depth (m) Static temperature(℃) Static temperature gradient (℃ / 100m) 6800 141.174 2.08 6850 142.291 2.23 6900 143.126 1.67 6950 144.054 1.86 7000 145.246 2.38 7050 146.235 1.98 7100 147.406 2.34

[0084] The flow temperature gradient of the first test point in the reservoir is the flow temperature gradient of the last test point of the flow temperature-vertical depth curve, such as 0.55℃ / 100m in Table 1. The flow temperature of the first test point in the reservoir is the flow temperature of the last test point of the flow temperature-vertical depth curve, such as 154.53℃ in Table 1. The static temperature of the first test point in the reservoir is the static temperature of the last test point of the static temperature-vertical depth curve, such as 147.406℃ in Table 2.

[0085] Among them, the preset height difference between adjacent test points in the reservoir in the above-mentioned carbonate oil and gas reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir can be input by the user to the electronic device executing the embodiment of the present method, or sent by other devices to the electronic device executing the embodiment of the present method.

[0086] S202, determining the target number of test points in the reservoir according to a preset height difference, a flow temperature gradient variation factor of the reservoir, a preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir.

[0087] In this embodiment, the preset height difference between adjacent test points in the reservoir of the carbonate oil and gas reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir have been determined. Therefore, the target number of test points in the reservoir is determined based on the relationship between the target number of test points in the reservoir and the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir.

[0088] S203, according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, the producing height of the reservoir is obtained, and the producing height is the height from the bottom of the production well to the position where the fluid in the reservoir does not flow.

[0089] In this embodiment, the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference between adjacent test points have been determined, so the production height of the reservoir is obtained. The production height is the height from the bottom of the production well to the position where the fluid in the reservoir does not flow. Figure 3As shown, the production height h of the reservoir of the production well 100 has a critical point P, H2 is the depth of the critical point P, below point P, the fluid does not flow, and above point P, the fluid can be used, and the flow temperature is higher than the static temperature at the same depth. As the depth increases, the difference between the flow temperature and the static temperature gradually decreases until point P, when the flow temperature and the static temperature are balanced and equal. The depth corresponding to the place where the flow temperature and the static temperature are equal, that is, the critical point P, can obtain the production height h of the reservoir.

[0090] S204. Control the drilling depth of the drill pipe in the production well according to the production height of the reservoir.

[0091] In this embodiment, the production height of the reservoir has been determined, so the depth of the drill pipe drilling in the production well can be controlled. For example, the production well can be increased by drilling to the critical point P, but it cannot exceed this position to avoid water. According to the production height of the existing reservoir in the production well, the oil and gas enrichment of the entire fault zone can be evaluated, the production potential of the fault zone can be reasonably evaluated, and advantageous production can be carried out; it is used in the calculation of proven reserves, one of the effective methods for determining the oil bottom height, improving the accuracy of reserve calculation, and guiding the preparation of development plans; guiding the determination of the reasonable production capacity of a single well, optimizing the reasonable working system, the greater the oil column height determined according to the production height of the reservoir, the higher the reasonable production capacity of the single well, and then controlling the depth of the drill pipe drilling in the single well to increase the production capacity.

[0092] The present application provides a method for controlling the exploitation of a carbonate oil and gas reservoir, which obtains a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient variation factor of the reservoir, a preset static temperature gradient, the depth of a production well in the carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of a first test point in the reservoir; wherein at least one test point is located in a production well in a carbonate oil and gas reservoir, at least one test point includes a first test point, and other test points are located in a reservoir below the production well; a target number of test points in the reservoir is determined according to the preset height difference, the flow temperature gradient variation factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; a producing height of the reservoir is obtained according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference; the producing height is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir; and the depth of drilling by the drill pipe in the production well is controlled according to the producing height of the reservoir. Through the above method, the utilization height of carbonate oil and gas reservoirs can be accurately determined. When producing wells, the depth of drill pipe drilling in the production wells can be controlled to improve the production capacity of the production wells. At the same time, it provides technical support for evaluating the vertical oil and gas enrichment degree of the entire block of carbonate oil and gas reservoirs; provides a basis for the formulation of a reasonable working system for a single well, so as to make full use of the formation energy and increase the water-free oil production period of a single well; and can also provide a reference for the prediction of the oil-water interface and guide the deployment of new wells to drill the target layer thickness to improve the utilization of reserves.

[0093] exist Figure 2 Based on the embodiments shown, in some embodiments, Figure 5 A flowchart of a carbonate oil and gas reservoir production control method provided in another embodiment of the present application is shown in FIG. Figure 5 As shown, the method of this embodiment may include:

[0094] S501. Obtain a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in the carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of the first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and other test points are located in the reservoir below the production well.

[0095] In this embodiment, the specific implementation process of S501 can be found in Figure 2 The relevant description of the illustrated embodiment will not be repeated here.

[0096] S502, obtaining a first correspondence between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity.

[0097] In this embodiment, the flow temperature gradient and the flow temperature gradient change factor of the first test point have been determined. Therefore, the flow temperature gradient of each test point from the second test point to the last test point in the reservoir is determined based on the flow temperature gradient and the flow temperature gradient change factor of the first test point, and then the first corresponding relationship between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number is determined, where the target number is the total number of all test points to be determined in the reservoir.

[0098] Optionally, the first corresponding relationship is expressed by the following formula 1:

[0099] G 流n =G 流1 -(n-1)×ΔG 流 Formula 1

[0100] Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets.

[0101] In this embodiment, according to the known G 流1 and ΔG 流 , the flow temperature gradient calculation formula as shown in Formula 1 is determined, and the flow temperature gradient of each test point in the target number of test points in the reservoir can be obtained. 流n , G 流1 and ΔG 流 The unit of is, for example, °C / 100m, and the unit of n is, for example, piece.

[0102] S503. According to the first corresponding relationship, obtain a second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity.

[0103] In this embodiment, on the basis of the first corresponding relationship shown in Formula 1, the flow temperature of each test point from the second test point to the last test point in the reservoir is determined according to the flow temperature of the first test point, the preset height difference, and the flow temperature gradient of the second test point that have been determined, and then the second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number is determined.

[0104] Optionally, the second corresponding relationship is expressed by the following formula 2:

[0105]

[0106] Among them, T流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

[0107] In this embodiment, specifically, the flow temperature at the second test point is: The flow temperature at the third test point is: By analogy, the flow temperature of the last test point is obtained as follows: Add the left and right sides of the flow temperature calculation formula for all test points from the second test point to the last test point, and get formula 6: Combined with formula 1, the series sum of formula 6 is performed to obtain formula 2. According to formula 2, the flow temperature of each test point in the target number of test points in the reservoir can be obtained. 流n , T 流1 The unit of is, for example, °C, and ΔH is, for example, 50m.

[0108] S504, obtaining a third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target quantity.

[0109] In this embodiment, the static temperature, preset static temperature gradient, and preset height difference of the first test point have been determined. Therefore, the static temperature of each test point in the reservoir from the second test point to the last test point is determined based on the static temperature, preset static temperature gradient, and preset height difference of the first test point, and then the third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target number is determined.

[0110] Optionally, the third corresponding relationship is expressed by the following formula 3:

[0111]

[0112] Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

[0113] In this embodiment, according to the known T 静1 , G 静 and ΔH, the static temperature calculation formula shown in Formula 3 is determined, which can obtain the static temperature of each test point among the target number of test points in the reservoir. 静n and T 静1 The unit is, for example, °C, G 静 The unit is, for example, °C / 100m.

[0114] S505: Determine the target quantity according to the second corresponding relationship and the third corresponding relationship.

[0115] In this embodiment, the second corresponding relationship and the third corresponding relationship have been determined, and therefore, the target quantity is determined according to the second corresponding relationship and the third corresponding relationship.

[0116] Optionally, according to the above formula 2 and formula 3, obtain formula 4;

[0117] According to formula 4, the target quantity is obtained;

[0118] Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

[0119] In this embodiment, the values ​​of A, B, and C are substituted into Formula 4 to obtain the target number n, wherein the solved n has two values, and the positive value thereof is the final value of n.

[0120] S506. Obtain the producing height of the reservoir according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference. The producing height is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir.

[0121] In this embodiment, optionally, the producing height of the reservoir is obtained according to the following formula 5:

[0122] h=n×ΔH-(HH 1 ) Formula 5

[0123] Where h represents the producing height of the reservoir, H 1 represents the depth of the first test point, and H represents the depth of the production well.

[0124] Specifically, according to the known depth H of the first test point 1 , the depth H of the production well, the target number n, and the reservoir production height are obtained through formula 5.

[0125] S507. Control the drilling depth of the drill pipe in the production well according to the production height of the reservoir.

[0126] In this embodiment, the specific implementation process of S507 can be found in Figure 2 The relevant description of the illustrated embodiment will not be repeated here.

[0127] The present application provides a method for controlling the exploitation of a carbonate oil and gas reservoir, by obtaining a preset height difference between adjacent test points in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, the depth of a production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in a production well in a carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well, obtaining a first correspondence between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor, and a target number, and obtaining the last test point according to the first correspondence. A second correspondence between the flow temperature of a test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number is obtained; a third correspondence between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target number is obtained; the target number is determined based on the second and third correspondences; the mobilization height of the reservoir is obtained based on the target number of test points in the reservoir, the depth of the first test point, the depth of the production well and the preset height difference; the mobilization height is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir; the depth of the drill pipe drilling in the production well is controlled based on the mobilization height of the reservoir. Through the above method, the utilization height of carbonate oil and gas reservoirs can be accurately determined. When producing wells, the depth of drill pipe drilling in the production wells can be controlled to improve the production capacity of the production wells. At the same time, it provides technical support for evaluating the vertical oil and gas enrichment degree of the entire block of carbonate oil and gas reservoirs; provides a basis for the formulation of a reasonable working system for a single well, so as to make full use of the formation energy and increase the water-free oil production period of a single well; and can also provide a reference for the prediction of the oil-water interface and guide the deployment of new wells to drill the target layer thickness to improve the utilization of reserves.

[0128] Figure 6 A schematic diagram of the structure of a carbonate oil and gas reservoir production control device provided in an embodiment of the present application, such as Figure 6 As shown, the carbonate oil and gas reservoir production control device 600 of this embodiment includes: an acquisition module 601 , a determination module 602 , a processing module 603 and a control module 604 .

[0129] The acquisition module 601 is used to obtain the preset height difference between adjacent test points in the reservoir in the carbonate oil and gas reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in the production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well.

[0130] Determination module 602 is used to determine the target number of test points in the reservoir based on a preset height difference, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir.

[0131] Processing module 603 is used to obtain the reservoir's production height based on the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference. The production height is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir.

[0132] The control module 604 is used to control the drilling depth of the drill pipe in the production well according to the production height of the reservoir.

[0133] Based on any of the above embodiments, the determination module 602 is specifically configured to:

[0134] Obtain a first correspondence between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number; based on the first correspondence, obtain the second correspondence between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number; obtain a third correspondence between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target number; determine the target number based on the second and third correspondences.

[0135] Based on any of the above embodiments, the first corresponding relationship is expressed by the following formula 1:

[0136] G 流n =G 流1 -(n-1)×ΔG 流 Formula 1

[0137] Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets.

[0138] Based on any of the above embodiments, the second corresponding relationship is expressed by the following formula 2:

[0139]

[0140] Among them, T 流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

[0141] Based on any of the above embodiments, the third corresponding relationship is expressed by the following formula 3:

[0142]

[0143] Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

[0144] Based on any of the above embodiments, the determination module 602 is specifically configured to:

[0145] According to Formula 2 and Formula 3, Formula 4 is obtained; according to Formula 4, the target quantity is obtained.

[0146] Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

[0147] Based on any of the above embodiments, the processing module 603 is specifically configured to:

[0148] According to the following formula 5, the mobilization height is obtained:

[0149] h=n×ΔH-(HH 1 ) Formula 5

[0150] Where h represents the producing height of the reservoir, H 1 represents the depth of the first test point, and H represents the depth of the production well.

[0151] The device of this embodiment can be used to execute the technical solution of any of the above-mentioned method embodiments. Its implementation principle and technical effects are similar and will not be repeated here.

[0152] Figure 7 This is a schematic diagram of the structure of a carbonate oil and gas reservoir production control device provided in another embodiment of the present application. Figure 7 As shown, the carbonate oil and gas reservoir production control device 700 of this embodiment includes: a memory 701 and a processor 702. The memory 701 and the processor 702 are connected via a bus.

[0153] The memory 701 is used to store program instructions.

[0154] The processor 702 is used to call the program instructions in the memory to execute:

[0155] Obtain the preset height difference between adjacent test points in the carbonate oil and gas reservoir, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; wherein at least one test point is located in the production well in the carbonate oil and gas reservoir, at least one test point includes the first test point, and the other test points are located in the reservoir below the production well. According to the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir, determine the target number of test points in the reservoir. According to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, obtain the production height of the reservoir, which is the height from the bottom of the production well to the position where the fluid does not flow in the reservoir. According to the production height of the reservoir, control the depth of the drill pipe drilling in the production well.

[0156] Based on any of the above embodiments, the processor 702 is specifically configured to:

[0157] Obtain a first correspondence between the flow temperature gradient of the last test point, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number; based on the first correspondence, obtain the second correspondence between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target number; obtain a third correspondence between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target number; determine the target number based on the second and third correspondences.

[0158] Based on any of the above embodiments, the first corresponding relationship is expressed by the following formula 1:

[0159] G 流n =G 流1 -(n-1)×ΔG 流 Formula 1

[0160] Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets.

[0161] Based on any of the above embodiments, the second corresponding relationship is expressed by the following formula 2:

[0162]

[0163] Among them, T 流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

[0164] Based on any of the above embodiments, the third corresponding relationship is expressed by the following formula 3:

[0165]

[0166] Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

[0167] Based on any of the above embodiments, the processor 702 is specifically configured to:

[0168] According to Formula 2 and Formula 3, Formula 4 is obtained; according to Formula 4, the target quantity is obtained.

[0169] Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

[0170] Based on any of the above embodiments, the processor 702 is specifically configured to:

[0171] According to the following formula 5, the mobilization height is obtained:

[0172] h=n×ΔH-(HH 1 ) Formula 5

[0173] Where h represents the producing height of the reservoir, H 1 represents the depth of the first test point, and H represents the depth of the production well.

[0174] The device of this embodiment can be used to execute the technical solution of any of the above-mentioned method embodiments. Its implementation principle and technical effects are similar and will not be repeated here.

[0175] Figure 8 A schematic diagram of the structure of a carbonate oil and gas reservoir production control device provided in another embodiment of the present application is shown in FIG. Figure 8As shown, for example, the production control device 800 of the carbonate oil and gas reservoir can be provided as a server or a computer. Figure 8 , the production control device 800 for carbonate oil and gas reservoirs includes a processing component 801, which further includes one or more processors, and a memory resource represented by a memory 802, for storing instructions that can be executed by the processing component 801, such as an application. The application stored in the memory 802 may include one or more modules, each corresponding to a set of instructions. In addition, the processing component 801 is configured to execute instructions to perform any of the above method embodiments.

[0176] The device 800 may also include a power supply component 803 configured to perform power management of the device 800, a wired or wireless network interface 804 configured to connect the device 800 to a network, and an input / output (I / O) interface 805. The device 800 may operate based on an operating system stored in the memory 802, such as Windows Server™, Mac OS X™, Unix™, Linux™, FreeBSD™ or the like.

[0177] The present application also provides a computer-readable storage medium, in which computer-executable instructions are stored. When a processor executes the computer-executable instructions, the above-mentioned carbonate oil and gas reservoir exploitation control method is implemented.

[0178] The computer-readable storage medium mentioned above can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, magnetic disk or optical disk. The readable storage medium can be any available medium that can be accessed by a general or special-purpose computer.

[0179] An exemplary readable storage medium is coupled to a processor so that the processor can read information from the readable storage medium and write information to the readable storage medium. Of course, the readable storage medium can also be a component of the processor. The processor and the readable storage medium can be located in an application specific integrated circuit (Application Specific Integrated Circuits, referred to as: ASIC). Of course, the processor and the readable storage medium can also exist as discrete components in the production control device of the carbonate oil and gas reservoir.

[0180] Those skilled in the art can understand that all or part of the steps of implementing the above-mentioned method embodiments can be completed by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When the program is executed, the steps of the above-mentioned method embodiments are executed; and the aforementioned storage medium includes: ROM, RAM, disk or optical disk and other media that can store program codes.

[0181] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit it. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for controlling the production of carbonate oil and gas reservoirs, characterized in that: include: Obtaining a preset height difference between adjacent test points in a reservoir in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in the carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of a first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, the at least one test point includes the first test point, and other test points are located in a reservoir below the production well; Determine the target number of test points in the reservoir according to the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; According to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference, the producing height of the reservoir is obtained, wherein the producing height is the height from the bottom of the production well to the position where the fluid in the reservoir does not flow; Controlling the drilling depth of the drill pipe in the production well according to the production height of the reservoir; Wherein, determining the target number of test points in the reservoir according to the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir includes: Obtaining a first corresponding relationship between a flow temperature gradient of a last test point, a flow temperature gradient of a first test point, a flow temperature gradient variation factor, and a target quantity; The first corresponding relationship is expressed by the following formula 1: G 流n =G 流1 -(n-1)×ΔG 流 Formula 1 Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets; According to the first corresponding relationship, a second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity is obtained; Obtaining a third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target quantity; Determining the target quantity according to the second corresponding relationship and the third corresponding relationship; Among them, the target number is the total number of test points between the depth of the critical point and the depth of the first test point; the position of the critical point is the position where the fluid does not flow downward along the vertical depth; the flow temperature at the critical point is the same as the static temperature.

2. The method according to claim 1, characterized in that The second corresponding relationship is expressed by the following formula 2: Among them, T 流n Indicates the flow temperature at the last test point, T 流1 It indicates the flow temperature at the first test point, and ΔH indicates the preset height difference.

3. The method according to claim 2, characterized in that The third corresponding relationship is expressed by the following formula 3: Among them, T 静n Indicates the static temperature of the last test point, T 静1 Represents the static temperature of the first test point, G 静 Indicates the preset static temperature gradient.

4. The method according to claim 3, characterized in that The determining the target quantity according to the second corresponding relationship and the third corresponding relationship includes: According to Formula 2 and Formula 3, Formula 4 is obtained; According to the formula 4, the target quantity is obtained; Formula 4 is Where A = ΔH × ΔG 流 , B = ΔH × (2 × G 静 -2×G 流1 -ΔG 流 ), C = 200 × (T 静1 -T 流1 )+2×ΔH×G 流1 .

5. The method according to any one of claims 1 to 4, characterized in that: The obtaining of the producing height of the reservoir according to the target number of test points in the reservoir, the depth of the first test point, the depth of the production well, and the preset height difference comprises: According to the following formula 5, the mobilization height is obtained: h=n×ΔH-(H-H1) Formula 5 Among them, h represents the production height of the reservoir, H1 represents the depth of the first test point, and H represents the depth of the production well.

6. A carbonate oil and gas reservoir production control device, characterized in that: include: An acquisition module, used to acquire a preset height difference between adjacent test points in a reservoir in a carbonate oil and gas reservoir, a flow temperature gradient change factor of the reservoir, a preset static temperature gradient, a depth of a production well in the carbonate oil and gas reservoir, and a flow temperature gradient, a flow temperature, and a static temperature of a first test point in the reservoir; wherein at least one test point is located in a production well in the carbonate oil and gas reservoir, the at least one test point includes the first test point, and other test points are located in the reservoir below the production well; A determination module, for determining a target number of test points in the reservoir according to the preset height difference, the flow temperature gradient change factor of the reservoir, the preset static temperature gradient, the depth of the production well in the carbonate oil and gas reservoir, and the flow temperature gradient, flow temperature, and static temperature of the first test point in the reservoir; A processing module, configured to obtain a producing height of the reservoir according to a target number of test points in the reservoir, a depth of the first test point, a depth of the production well, and the preset height difference, wherein the producing height is a height from the bottom of the production well to a position where fluid does not flow in the reservoir; A control module, used to control the drilling depth of the drill pipe in the production well according to the production height of the reservoir; Wherein, the determination module is specifically used for: Obtaining a first corresponding relationship between a flow temperature gradient of a last test point, a flow temperature gradient of a first test point, a flow temperature gradient variation factor, and a target quantity; The first corresponding relationship is expressed by the following formula 1: G 流n =G 流1 -(n-1)×ΔG 流 Formula 1 Among them, G 流n Represents the flow temperature gradient at the last test point, G 流1 Represents the flow temperature gradient at the first test point, ΔG 流 represents the flow temperature gradient change factor, and n represents the number of targets; According to the first corresponding relationship, a second corresponding relationship between the flow temperature of the last test point, the flow temperature of the first test point, the preset height difference, the flow temperature gradient of the first test point, the flow temperature gradient change factor and the target quantity is obtained; Obtaining a third corresponding relationship between the static temperature of the last test point, the static temperature of the first test point, the preset static temperature gradient, the preset height difference and the target quantity; Determining the target quantity according to the second corresponding relationship and the third corresponding relationship; Among them, the target number is the total number of test points between the depth of the critical point and the depth of the first test point; the position of the critical point is the position where the fluid does not flow downward along the vertical depth; the flow temperature at the critical point is the same as the static temperature.

7. A carbonate oil and gas reservoir production control device, characterized in that: include: Memory and processor; The memory is used to store program instructions; The processor is used to call the program instructions in the memory to execute the carbonate oil and gas reservoir production control method as described in any one of claims 1-5.

8. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer program instructions, and when the computer program instructions are executed, the production control method for carbonate oil and gas reservoirs according to any one of claims 1 to 5 is implemented.

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