Method, device, computer equipment and storage medium for determining dynamic reserves

Abstract

The present application provides a method, device, computer equipment and storage medium for determining dynamic reserves, which belongs to the field of oil and gas development technology. The method includes: obtaining the pressure, temperature and production of the oil well to be tested; determining the volume coefficient of crude oil in the oil well according to the temperature and pressure, and determining the compression coefficient of the oil well; determining the flow characteristics of the oil well according to the production, volume coefficient and compression coefficient, and the flow characteristics are used to indicate the flow stage of the oil well; when the flow characteristics are used to indicate that the flow stage of the oil well is a quasi-stable flow stage, determining the target production corresponding to the quasi-stable flow stage of the oil well; determining the dynamic reserves of the oil well according to the target production, volume coefficient and compression coefficient. The method for determining the dynamic reserves provided in the embodiment of the present application can determine the dynamic reserves of the oil well based on the two dimensions of crude oil storage and reservoir seepage capacity, so as to improve the accuracy of the obtained dynamic reserves of the oil well.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas development, and in particular to a method, device, computer equipment and storage medium for determining dynamic reserves. Background Art

[0002] At present, fracturing transformation technology is an important technology to increase oil well production. Among them, the greater the dynamic reserves after the oil well transformation, the greater the increased production of the oil well. Therefore, in order to determine the increased production of the oil well after fracturing transformation, it is necessary to determine the dynamic reserves of the oil well after fracturing transformation.

[0003] In the related art, the dynamic reserves of oil wells are determined by the ground microseismic method. The method includes: obtaining seismic waves of multiple shot point sources received by the detection point; determining the distribution of crude oil and rocks in the reservoir according to the received seismic waves; and determining the dynamic reserves of the oil well after fracturing transformation according to the distribution of crude oil and rocks in the reservoir.

[0004] However, the dynamic reserves determined by the ground microseismic method can only reflect the changes in the crude oil storage volume in the oil well, and the dynamic reserves of the oil well are related to the crude oil storage volume and the seepage capacity of the reservoir. When the reservoir seepage capacity of the oil well is low, even if the crude oil storage volume in the oil well is large, the dynamic reserves of the oil well are also low. Therefore, the accuracy of the dynamic reserves of the oil well obtained by the above method is low. Summary of the invention

[0005] The embodiment of the present application provides a method, device, computer equipment and storage medium for determining dynamic reserves, which can improve the accuracy of drilling compliance information in the exploration area. The technical solution is as follows:

[0006] In one aspect, the present application provides a method for determining dynamic reserves, the method comprising:

[0007] Obtain the pressure, temperature and production of the oil well to be tested;

[0008] Determining a volume coefficient of crude oil in the oil well according to the temperature and the pressure, and determining a compressibility coefficient of the oil well;

[0009] Determining the flow characteristics of the oil well according to the production, the volume coefficient and the compressibility coefficient, wherein the flow characteristics are used to indicate the flow stage of the oil well;

[0010] When the flow characteristics are used to indicate that the flow stage of the oil well is a quasi-stable flow stage, determining a target production corresponding to when the oil well is in the quasi-stable flow stage;

[0011] The dynamic reserves of the oil well are determined according to the target production, the volume coefficient and the compressibility coefficient.

[0012] In a possible implementation, determining the volume coefficient of the crude oil in the oil well according to the temperature and the pressure includes:

[0013] According to the temperature, determining a temperature coefficient matching the temperature;

[0014] According to the temperature coefficient and the pressure, the volume coefficient of the crude oil in the oil well is determined by the following formula 1;

[0015] Formula 1: B = 0.952-2.154×10 -4 P R +10 A

[0016] Wherein, B represents the volume coefficient of crude oil in the oil well, P R represents the pressure, and A represents the temperature coefficient.

[0017] In another possible implementation, determining, according to the temperature, a temperature coefficient matching the temperature includes:

[0018] According to the temperature, a temperature coefficient matching the temperature is determined by the following formula 5;

[0019] Formula 5: A = 0.1336 (2.647 × 10 -2 T-1)-1.2676

[0020] Wherein, A represents the temperature coefficient, and T represents the temperature.

[0021] In another possible implementation, determining the compressibility coefficient of the oil well includes:

[0022] Obtaining the compressibility coefficient of the rock, the compressibility coefficient of the crude oil and the compressibility coefficient of water in the oil well; and determining the saturation of the crude oil and the saturation of water in the oil well;

[0023] According to the compression coefficient of the rock, the compression coefficient of the crude oil, the compression coefficient of the water, the saturation of the crude oil and the saturation of the water, the compression coefficient of the oil well is determined by the following formula 2;

[0024] Formula 2: C t =C r +C o S o +C w S w

[0025] Among them, C t represents the compressibility factor of the oil well, C rrepresents the compressibility of the rock, C o represents the compressibility coefficient of the crude oil, C w represents the compressibility coefficient of water, S o Indicates the saturation of the crude oil, S w Indicates the saturation of the water.

[0026] In another possible implementation, determining the flow characteristics of the oil well according to the production, the volume coefficient and the compressibility coefficient includes:

[0027] Determining a change in bottom hole pressure of the oil well according to the production, the volume coefficient and the compressibility coefficient;

[0028] Determining, according to the change in the bottom hole pressure, a first logarithmic value corresponding to the bottom hole pressure and a second logarithmic value corresponding to the change in the bottom hole pressure;

[0029] The flow characteristics of the oil well are determined based on the first logarithmic value and the second logarithmic value.

[0030] In another possible implementation, determining the change in bottom hole pressure of the oil well according to the production, the volume coefficient, and the compressibility coefficient includes:

[0031] Obtaining the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well;

[0032] According to the production, the volume coefficient, the compression coefficient, the flow velocity duration of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well, the change in the bottom hole pressure of the oil well is determined by the following formula three;

[0033] Formula 3:

[0034] Wherein, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V Prepresents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well.

[0035] In another possible implementation, determining, according to the change in the bottom hole pressure, a first logarithmic value corresponding to the bottom hole pressure and a second logarithmic value corresponding to the change in the bottom hole pressure includes:

[0036] According to the change in the bottom hole pressure and the flow time of the crude oil in the oil well, the first logarithmic value corresponding to the bottom hole pressure is determined by the following formula 6, and according to the production, the volume coefficient, the pore volume of the reservoir where the oil well is located, the compression coefficient of the oil well and the flow time of the crude oil in the oil well, the second logarithmic value corresponding to the change in the bottom hole pressure is determined by the following formula 7;

[0037] Formula 6:

[0038] Formula 7:

[0039] Wherein, M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in the bottom hole pressure, q represents the production, B represents the volume coefficient, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well.

[0040] In another possible implementation, determining the flow characteristic of the oil well according to the first logarithmic value and the second logarithmic value includes:

[0041] When the first logarithmic value and the second logarithmic value are the same and are both first values, the flow characteristic of the oil well is determined to indicate that the flow stage of the oil well is a quasi-stable flow stage.

[0042] In another possible implementation, determining the dynamic reserve of the oil well according to the target production, the volume coefficient and the compressibility coefficient includes:

[0043] determining the volume of fracturing fluid in the oil well;

[0044] Determining the volume of crude oil in the pores of the reservoir where the oil well is located according to the target production, the volume coefficient and the compressibility coefficient;

[0045] The difference between the volume of crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid is determined as the dynamic reserve of the oil well.

[0046] In another possible implementation, determining the volume of crude oil in the pores of the reservoir where the oil well is located according to the target production, the volume coefficient, and the compressibility coefficient includes:

[0047] Acquire the duration of the oil well being in the quasi-stable flow stage, and the change in bottom hole pressure of the oil well corresponding to the quasi-stable flow stage;

[0048] The volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4 according to the duration, the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, the volume coefficient and the compressibility coefficient;

[0049] Formula 4:

[0050] Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of the crude oil in the oil well, C t represents the compression coefficient of the oil well, Δp represents the change in the bottom hole pressure of the oil well, and t represents the time length.

[0051] On the other hand, the present application provides a device for determining dynamic reserves, the device comprising:

[0052] An acquisition module, used to acquire the pressure, temperature and production of the oil well to be tested;

[0053] A first determination module, used to determine the volume coefficient of the crude oil in the oil well and the compressibility coefficient of the oil well according to the temperature and the pressure;

[0054] A second determination module is used to determine the flow characteristics of the oil well according to the production, the volume coefficient and the compressibility coefficient, wherein the flow characteristics are used to indicate the flow stage of the oil well;

[0055] A third determination module is used to determine a target production corresponding to when the oil well is in the quasi-stable flow stage when the flow characteristic is used to indicate that the flow stage of the oil well is in the quasi-stable flow stage;

[0056] The fourth determination module is used to determine the dynamic reserves of the oil well according to the target production, the volume coefficient and the compression coefficient.

[0057] In a possible implementation, the first determination module is used to determine, according to the temperature, a temperature coefficient matching the temperature; and to determine, according to the temperature coefficient and the pressure, a volume coefficient of the crude oil in the oil well by the following formula 1;

[0058] Formula 1: B = 0.952-2.154×10 -4 P R +10 A

[0059] Wherein, B represents the volume coefficient of crude oil in the oil well, P R represents the pressure, and A represents the temperature coefficient.

[0060] In another possible implementation, the first determination module is used to obtain the compressibility coefficient of the rock, the compressibility coefficient of the crude oil, and the compressibility coefficient of water in the oil well; and determine the saturation of the crude oil and the saturation of water in the oil well;

[0061] According to the compression coefficient of the rock, the compression coefficient of the crude oil, the compression coefficient of the water, the saturation of the crude oil and the saturation of the water, the compression coefficient of the oil well is determined by the following formula 2;

[0062] Formula 2: C t =C r +C o S o +C w S w

[0063] Among them, C t represents the compressibility factor of the oil well, C r represents the compressibility of the rock, C o represents the compressibility coefficient of the crude oil, C w represents the compressibility coefficient of water, S o Indicates the saturation of the crude oil, S w Indicates the saturation of the water.

[0064] In another possible implementation, the second determination module is used to determine the change in the bottom hole pressure of the oil well based on the production, the volume coefficient and the compression coefficient; determine a first logarithmic value corresponding to the bottom hole pressure and a second logarithmic value corresponding to the change in the bottom hole pressure based on the change in the bottom hole pressure; and determine the flow characteristics of the oil well based on the first logarithmic value and the second logarithmic value.

[0065] In another possible implementation, the second determination module is used to obtain the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well; according to the production, the volume coefficient, the compression coefficient, the flow rate time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well, determine the change in the bottom hole pressure of the oil well through the following formula three;

[0066] Formula 3:

[0067] Wherein, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well.

[0068] In another possible implementation, the second determination module is used to determine a first logarithmic value corresponding to the bottom hole pressure according to the change in the bottom hole pressure and the flow time of the crude oil in the oil well by using the following formula 6, and to determine a second logarithmic value corresponding to the change in the bottom hole pressure according to the production, the volume coefficient, the pore volume of the reservoir where the oil well is located, the compressibility coefficient of the oil well and the flow time of the crude oil in the oil well by using the following formula 7;

[0069] Formula 6:

[0070] Formula 7:

[0071] Wherein, M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in the bottom hole pressure, q represents the production, B represents the volume coefficient, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well.

[0072] In another possible implementation, the second determination module is used to determine that the flow characteristics of the oil well are used to indicate that the flow stage of the oil well is a quasi-stable flow stage when the first logarithmic value and the second logarithmic value are the same and are both first values.

[0073] In another possible implementation, the fourth determination module is used to determine the volume of the fracturing fluid in the oil well; determine the volume of the crude oil in the pores of the reservoir where the oil well is located based on the target production, the volume coefficient and the compression coefficient; and determine the difference between the volume of the crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid as the dynamic reserve of the oil well.

[0074] In another possible implementation, the fourth determination module is used to obtain the duration of the oil well being in the quasi-stable flow stage, and the amount of change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage; according to the duration, the amount of change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, the volume coefficient and the compression coefficient, the volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4;

[0075] Formula 4:

[0076] Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of the crude oil in the oil well, C t represents the compression coefficient of the oil well, Δp represents the change in the bottom hole pressure of the oil well, and t represents the time length.

[0077] On the other hand, an embodiment of the present application provides a computer device, comprising: a processor and a memory, wherein the memory stores at least one program code, and the at least one program code is loaded and executed by the processor to implement the operations performed in the method for determining dynamic reserves described in any of the above possible implementations.

[0078] On the other hand, an embodiment of the present application provides a computer-readable storage medium, in which at least one program code is stored, and the at least one program code is loaded and executed by a processor to implement the operations performed in the method for determining dynamic reserves described in any possible implementation method described above.

[0079] The beneficial effects of the technical solution provided by the embodiments of the present application include at least:

[0080] The embodiment of the present application provides a method for determining dynamic reserves. Since the flow stage of the oil well is determined by the pressure, temperature and production of the oil well, and the pressure, temperature and production of the oil well are all related to the seepage capacity of the reservoir where the oil well is located, when the dynamic reserves of the oil well are determined by the target production corresponding to the quasi-stable flow stage of the oil well, both the crude oil storage capacity and the seepage capacity of the reservoir are considered. It can be seen that the method for determining dynamic reserves provided by the embodiment of the present application can determine the dynamic reserves of the oil well based on the two dimensions of crude oil storage capacity and reservoir seepage capacity, so the accuracy of the obtained dynamic reserves of the oil well is improved. BRIEF DESCRIPTION OF THE DRAWINGS

[0081] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0082] Figure 1 is a flow chart of a method for determining dynamic reserves according to an exemplary embodiment;

[0083] Figure 2 is a schematic diagram of a first logarithmic value curve and a second logarithmic value curve according to an exemplary embodiment;

[0084] Figure 3 is a block diagram of a device for determining dynamic reserves according to an exemplary embodiment;

[0085] Figure 4 The present invention is a structural block diagram of a computer device according to an exemplary embodiment. DETAILED DESCRIPTION

[0086] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below with reference to the accompanying drawings.

[0087] Figure 1 is a flow chart of a method for determining dynamic reserves according to an exemplary embodiment. Figure 1 , the method comprising:

[0088] 101. The computer equipment obtains the pressure, temperature and production of the oil well to be tested.

[0089] In a possible implementation, a pressure sensor, a temperature sensor, and a flow sensor are installed in the oil well to be tested. Accordingly, this step is: the computer device sends a detection instruction to the pressure sensor, the pressure sensor detects the pressure of the oil well, returns the detected pressure to the computer device, and the computer device obtains the pressure of the oil well; and the computer device sends a detection instruction to the temperature sensor, the temperature sensor detects the temperature of the oil well, returns the detected temperature to the computer device, and the computer device obtains the temperature of the oil well; and the computer device sends a detection instruction to the flow sensor, the flow sensor detects the flow rate of crude oil produced by the oil well, returns the detected flow rate to the computer device, and the computer device obtains the output of the oil well.

[0090] Optionally, the pressure sensor is an electronic pressure gauge, such as a storage pressure gauge. The temperature sensor is an electronic thermometer, such as an electronic infrared thermometer. The flow sensor is an ultrasonic flow meter.

[0091] It should be noted that the pressure of an oil well is the pressure of the oil well at the current time or the pressure of the oil well at multiple time points within a certain time period. For example, the pressure of an oil well is the pressure of the oil well at each time point within the opening time period. The temperature of an oil well is the temperature of the oil well at the current time or the temperature of the oil well at multiple time points within a certain time period. For example, the temperature of an oil well is the temperature of the oil well at each time point within the opening time period. The production of an oil well is the production of the oil well at the current time or the production of the oil well within a certain time period. For example, the production of an oil well is the production of the oil well within the opening time period.

[0092] One point that needs to be explained is that before the computer equipment obtains the pressure, temperature and production of the oil well to be tested, it needs to make sure that the oil well to be tested meets the test conditions.

[0093] In one possible implementation, the steps for the computer device to determine whether the oil well to be tested meets the test conditions are: the computer device obtains the volume of the bridge plug in the oil well; when the bridge plug in the oil well is fully dissolved to the volume of the bridge plug is zero, it is determined that the oil well to be tested meets the test conditions.

[0094] In another possible implementation, a computer device obtains the volume of the bridge plug in the oil well and the water-oil replacement rate of the oil well; when the bridge plug in the oil well is fully dissolved until the volume of the bridge plug is zero and the water-oil replacement rate of the oil well is 100%, it is determined that the oil well to be tested meets the test conditions.

[0095] 102. Computer equipment determines the volume coefficient of crude oil in the oil well based on temperature and pressure, as well as the compression coefficient of the oil well.

[0096] In a possible implementation, the volume coefficient of crude oil in the oil well is related to the temperature and pressure of the oil well. Accordingly, the steps of determining the volume coefficient of crude oil in the oil well according to the temperature and pressure of the oil well by the computer device are as follows: the computer device determines a temperature coefficient matching the temperature according to the temperature of the oil well; according to the temperature coefficient and the pressure of the oil well, the volume coefficient of crude oil in the oil well is determined by the following formula 1;

[0097] Formula 1: B = 0.952-2.154×10 -4 P R +10 A

[0098] Where B represents the volume coefficient of crude oil in the oil well, P R represents pressure and A represents temperature coefficient.

[0099] In a possible implementation, the step of the computer device determining the temperature coefficient matching the temperature according to the temperature of the oil well is as follows: the computer device determines the temperature coefficient matching the temperature according to the temperature of the oil well by using the following formula 5;

[0100] Formula 5: A = 0.1336 (2.647 × 10 -2 T-1)-1.2676; where A represents the temperature coefficient and T represents the temperature of the oil well.

[0101] In a possible implementation, the compression coefficient of the oil well is related to the compression coefficient of the rock, the compression coefficient of the crude oil, and the compression coefficient of the water in the oil well. Accordingly, the steps of determining the compression coefficient of the oil well by the computer device are: the computer device obtains the compression coefficient of the rock, the compression coefficient of the crude oil, and the compression coefficient of the water in the oil well; and determines the saturation of the crude oil and the saturation of the water in the oil well; according to the compression coefficient of the rock, the compression coefficient of the crude oil, the compression coefficient of the water, the saturation of the crude oil, and the saturation of the water, the compression coefficient of the oil well is determined by the following formula 2;

[0102] Formula 2: C t =C r +C o S o +C w S w

[0103] Among them, C t Indicates the compressibility of the oil well, C r Indicates the compression coefficient of rock, C o Indicates the compressibility of crude oil, C w Indicates the compressibility of water, S o Indicates the saturation of crude oil, S w Indicates water saturation.

[0104] 103. Computer equipment determines the flow characteristics of the oil well based on production, volume coefficient and compressibility coefficient.

[0105] Flow characteristics are used to indicate the flow stage of an oil well.

[0106] In one possible implementation, the steps for a computer device to determine the flow characteristics of an oil well based on production, volume coefficient, and compression coefficient are as follows: the computer device determines the change in bottom hole pressure of the oil well based on production, volume coefficient, and compression coefficient; determines a first logarithmic value corresponding to the bottom hole pressure and a second logarithmic value corresponding to the change in bottom hole pressure based on the change in bottom hole pressure; and determines the flow characteristics of the oil well based on the first logarithmic value and the second logarithmic value.

[0107] In a possible implementation, the step of determining the amount of change in the bottom hole pressure of the oil well according to the production, volume coefficient and compression coefficient by the computer device is as follows: the computer device obtains the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well;

[0108] According to the production, volume coefficient, compression coefficient, flow rate duration of crude oil in the oil well, viscosity of crude oil, bottom hole depth of the oil well, bottom hole permeability of the oil well, area of ​​the reservoir where the oil well is located, pore volume of the reservoir where the oil well is located, bottom hole resistance coefficient of the oil well, shape factor of the oil well and radius of the oil well, the change in bottom hole pressure of the oil well is determined by the following formula 3;

[0109] Formula 3:

[0110] Among them, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient of the crude oil in the oil well, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well.

[0111] In a possible implementation, the steps of determining, by a computer device, a first logarithmic value corresponding to the bottom hole pressure and a second logarithmic value corresponding to the change in the bottom hole pressure according to the change in the bottom hole pressure are as follows: the computer device determines the first logarithmic value corresponding to the bottom hole pressure according to the change in the bottom hole pressure and the flow time of the crude oil in the oil well by the following formula 6, and determines the second logarithmic value corresponding to the change in the bottom hole pressure according to the following formula 7 according to the production, volume coefficient, pore volume of the reservoir where the oil well is located, compression coefficient of the oil well and the flow time of the crude oil in the oil well;

[0112] Formula 6:

[0113] Formula 7:

[0114] Where M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in bottom hole pressure, q represents the production, B represents the volume coefficient of crude oil in the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well.

[0115] It should be noted that the first and second logarithmic values ​​are obtained by transforming the left and right sides of Formula 3. First, the two sides of Formula 3 are differentiated with respect to t to obtain:

[0116] Then, the left side of the formula is multiplied by t to obtain the logarithm of the first logarithmic value M, and the right side of the formula is multiplied by t to obtain the logarithm of the second logarithmic value N.

[0117] In one possible implementation, see Figure 2 , the first logarithmic value curve is used to represent the curve of the first logarithmic value changing with time, and the second logarithmic value curve is used to represent the curve of the second logarithmic value changing with time. The flow stages of the oil well include the first stage: wellbore reservoir flow stage, the second stage: skin effect transition stage, the third stage: fracture formation bilinear flow stage, the fourth stage: formation fracture transformation zone linear flow stage, the fifth stage: inter-fracture disturbance flow stage, and the sixth stage: quasi-stable flow stage.

[0118] In one possible implementation, the step in which a computer device determines the flow characteristics of an oil well based on a first logarithmic value and a second logarithmic value is as follows: when the first logarithmic value and the second logarithmic value are the same and are both first values, the computer device determines that the flow characteristics of the oil well are used to indicate that the flow stage of the oil well is a quasi-stable flow stage.

[0119] The first value is any value between 0.95 and 1.05, for example, 0.99, 1.00, 10.1, etc. In the embodiment of the present application, the first value is not specifically limited and can be modified and set as needed. Optionally, the first value is 1.

[0120] 104. When the flow characteristics are used to indicate that the flow stage of the oil well is a quasi-stable flow stage, the computer determines the target production corresponding to the quasi-stable flow stage of the oil well.

[0121] In a possible implementation, the computer device determines the target production corresponding to the quasi-stable flow stage when the oil well is in the quasi-stable flow stage according to the time period corresponding to the quasi-stable flow stage. Accordingly, this step is: the computer device determines the target time period corresponding to the quasi-stable flow stage; selects the production corresponding to the target time period from the production of the oil well; and uses the production corresponding to the target time period as the target production corresponding to the quasi-stable flow stage when the oil well is in the quasi-stable flow stage.

[0122] 105. Computer equipment determines the dynamic reserves of oil wells based on target production, volume coefficient and compression coefficient.

[0123] In a possible implementation, the dynamic reserves of an oil well are related to the target production corresponding to the oil well in the quasi-stable flow stage, the volume coefficient of crude oil in the oil well, and the compression coefficient of the oil well. Accordingly, the steps of determining the dynamic reserves of the oil well by the computer device according to the target production, volume coefficient, and compression coefficient are as follows: the computer device determines the volume of fracturing fluid in the oil well; determines the volume of crude oil in the pores of the reservoir where the oil well is located according to the target production, volume coefficient, and compression coefficient; determines the difference between the volume of crude oil in the pores of the reservoir where the oil well is located and the volume of fracturing fluid as the dynamic reserves of the oil well.

[0124] In a possible implementation, the computer device obtains the volume of the fracturing fluid injected into the oil well and the volume of the fracturing fluid discharged from the oil well, and determines that the difference between the volume of the fracturing fluid injected into the oil well and the volume of the fracturing fluid discharged from the oil well is the volume of the fracturing fluid in the oil well. Optionally, the volume of the fracturing fluid in the oil well is represented by V F express.

[0125] In a possible implementation, the steps of determining the volume of crude oil in the pores of the reservoir where the oil well is located according to the target production, volume coefficient and compression coefficient by the computer device are as follows: the computer device obtains the duration of the quasi-stable flow stage of the oil well and the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage; according to the duration, the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, volume coefficient and compression coefficient, the volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4;

[0126] Formula 4:

[0127] Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of crude oil in the oil well, C t represents the compression coefficient of the oil well, Δp represents the change in the bottom hole pressure of the oil well, and t represents the time.

[0128] One thing that needs to be explained is that Formula 4 is obtained by transforming Formula 3 after taking the derivative with respect to time. First, take the derivatives of both sides of Formula 3 with respect to t to obtain: Then, multiplying the formula by t gives After the change, we get: The volume of crude oil in the pores of the reservoir where the oil well is located is V s The pore volume V of the reservoir where the oil well is located P same.

[0129] In a possible implementation, the computer device determines the difference between the volume of crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid as the dynamic reserve of the oil well. Optionally, the dynamic reserve of the oil well is represented by V0, then V0 = Vs - V F ; Where Vs represents the volume of crude oil in the pores of the reservoir where the oil well is located, V F Indicates the volume of fracturing fluid in the oil well.

[0130] One point that needs to be explained is that the greater the dynamic reserves of the oil well, the greater the porosity of the reservoir where the oil well is located after transformation. Accordingly, the computer device can also determine the porosity of the reservoir where the oil well is located after transformation based on the dynamic reserves of the oil well. The steps for the computer device to determine the porosity of the reservoir are as follows: the computer device obtains the volume of the reservoir where the oil well is located; based on the dynamic reserves of the oil well and the volume of the reservoir where the oil well is located, the porosity of the reservoir where the oil well is located after transformation is determined by the following formula 8;

[0131] Formula 8:

[0132] Among them, φ L V represents the porosity of the reservoir after transformation. R It represents the volume of the reservoir where the oil well is located, and V0 represents the dynamic reserves of the oil well.

[0133] The embodiment of the present application provides a method for determining dynamic reserves. Since the flow stage of the oil well is determined by the pressure, temperature and production of the oil well, and the pressure, temperature and production of the oil well are all related to the seepage capacity of the reservoir where the oil well is located, when the dynamic reserves of the oil well are determined by the target production corresponding to the quasi-stable flow stage of the oil well, both the crude oil storage capacity and the seepage capacity of the reservoir are considered. It can be seen that the method for determining dynamic reserves provided by the embodiment of the present application can determine the dynamic reserves of the oil well based on the two dimensions of crude oil storage capacity and reservoir seepage capacity, so the accuracy of the obtained dynamic reserves of the oil well is improved.

[0134] Figure 3 is a block diagram of a device for determining dynamic reserves according to an exemplary embodiment. Figure 3 , the device comprises:

[0135] An acquisition module 301 is used to acquire the pressure, temperature and production of the oil well to be tested;

[0136] The first determination module 302 is used to determine the volume coefficient of the crude oil in the oil well and the compressibility coefficient of the oil well according to the temperature and pressure;

[0137] The second determination module 303 is used to determine the flow characteristics of the oil well according to the production, volume coefficient and compressibility coefficient, and the flow characteristics are used to indicate the flow stage of the oil well;

[0138] The third determination module 304 is used to determine the target production corresponding to the quasi-stable flow stage of the oil well when the flow characteristics are used to indicate that the flow stage of the oil well is a quasi-stable flow stage;

[0139] The fourth determination module 305 is used to determine the dynamic reserves of the oil well according to the target production, volume coefficient and compressibility coefficient.

[0140] In a possible implementation, the first determination module 302 is used to determine, according to the temperature, a temperature coefficient matching the temperature; and to determine, according to the temperature coefficient and the pressure, a volume coefficient of crude oil in the oil well by the following formula 1;

[0141] Formula 1: B = 0.952-2.154×10 -4 P R +10 A

[0142] Where B represents the volume coefficient of crude oil in the oil well, P R represents pressure and A represents temperature coefficient.

[0143] In another possible implementation, the first determination module is used to obtain the compressibility coefficient of the rock, the compressibility coefficient of the crude oil, and the compressibility coefficient of water in the oil well; and determine the saturation of the crude oil and the saturation of water in the oil well;

[0144] According to the rock compressibility, crude oil compressibility, water compressibility, crude oil saturation and water saturation, the oil well compressibility is determined by the following formula 2;

[0145] Formula 2: C t =C r +C o S o +C w S w

[0146] Among them, C t Indicates the compressibility of the oil well, C r Indicates the compression coefficient of rock, C o Indicates the compressibility of crude oil, C w Indicates the compressibility of water, S o Indicates the saturation of crude oil, S w Indicates water saturation.

[0147] In another possible implementation, the second determination module 303 is used to determine the change in the bottom hole pressure of the oil well based on the production, volume coefficient and compression coefficient; determine the first logarithmic value corresponding to the bottom hole pressure and the second logarithmic value corresponding to the change in the bottom hole pressure based on the change in the bottom hole pressure; and determine the flow characteristics of the oil well based on the first logarithmic value and the second logarithmic value.

[0148] In another possible implementation, the second determination module 303 is used to obtain the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well; according to the production, volume coefficient, compression coefficient, the flow rate time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well, the change in the bottom hole pressure of the oil well is determined by the following formula three;

[0149] Formula 3:

[0150] Among them, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well.

[0151] In another possible implementation, the second determination module 303 is used to determine the first logarithmic value corresponding to the bottom hole pressure according to the change in bottom hole pressure and the flow time of crude oil in the oil well through the following formula 6, and to determine the second logarithmic value corresponding to the change in bottom hole pressure according to the production, volume coefficient, pore volume of the reservoir where the oil well is located, compression coefficient of the oil well and the flow time of crude oil in the oil well through the following formula 7;

[0152] Formula 6:

[0153] Formula 7:

[0154] Where M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in bottom hole pressure, q represents the production, B represents the volume coefficient, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well.

[0155] In another possible implementation, the second determination module 303 is used to determine that the flow characteristics of the oil well are used to indicate that the flow stage of the oil well is a quasi-stable flow stage when the first logarithmic value and the second logarithmic value are the same and are both first values.

[0156] In another possible implementation, the fourth determination module 305 is used to determine the volume of the fracturing fluid in the oil well; determine the volume of the crude oil in the pores of the reservoir where the oil well is located based on the target production, volume coefficient and compression coefficient; and determine the difference between the volume of the crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid as the dynamic reserve of the oil well.

[0157] In another possible implementation, the fourth determination module 305 is used to obtain the duration of the oil well being in the quasi-stable flow stage and the amount of change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage; according to the duration, the amount of change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, the volume coefficient and the compression coefficient, the volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4;

[0158] Formula 4:

[0159] Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of crude oil in the oil well, C t represents the compression coefficient of the oil well, p represents the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, and t represents the duration.

[0160] The embodiment of the present application provides a device for determining dynamic reserves. Since the flow stage of the oil well is determined by the pressure, temperature and production of the oil well, and the pressure, temperature and production of the oil well are all related to the seepage capacity of the reservoir where the oil well is located, when the dynamic reserves of the oil well are determined by the target production corresponding to the quasi-stable flow stage of the oil well, both the crude oil storage capacity and the seepage capacity of the reservoir are considered. It can be seen that the device for determining dynamic reserves provided by the embodiment of the present application can determine the dynamic reserves of the oil well based on the two dimensions of crude oil storage capacity and reservoir seepage capacity, so the accuracy of the obtained dynamic reserves of the oil well is improved.

[0161] Figure 4 The structure block diagram of a terminal 400 provided by an exemplary embodiment of the present invention is shown. The terminal 400 may be: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III), an MP4 (Moving Picture Experts Group Audio Layer IV), a laptop computer or a desktop computer. The terminal 400 may also be called a user device, a portable terminal, a laptop terminal, a desktop terminal or other names.

[0162] Typically, the terminal 400 includes a processor 401 and a memory 402 .

[0163] The processor 401 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 401 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). The processor 401 may also include a main processor and a coprocessor. The main processor is a processor for processing data in the awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in the standby state. In some embodiments, the processor 401 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 401 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0164] The memory 402 may include one or more computer-readable storage media, which may be non-transitory. The memory 402 may also include a high-speed random access memory and a non-volatile memory, such as one or more disk storage devices and flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in the memory 402 is used to store at least one instruction, which is used to be executed by the processor 401 to implement the dynamic reserve determination method provided in the method embodiment of the present application.

[0165] In some embodiments, the terminal 400 may further optionally include: a peripheral device interface 403 and at least one peripheral device. The processor 401, the memory 402 and the peripheral device interface 403 may be connected via a bus or a signal line. Each peripheral device may be connected to the peripheral device interface 403 via a bus, a signal line or a circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 404, a display screen 405, a camera 406, an audio circuit 407, a positioning component 408 and a power supply 409.

[0166] The peripheral device interface 403 may be used to connect at least one peripheral device related to I / O (Input / Output) to the processor 401 and the memory 402. In some embodiments, the processor 401, the memory 402, and the peripheral device interface 403 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 401, the memory 402, and the peripheral device interface 403 may be implemented on a separate chip or circuit board, which is not limited in this embodiment.

[0167] The radio frequency circuit 404 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 404 communicates with the communication network and other communication devices through electromagnetic signals. The radio frequency circuit 404 converts the electrical signal into an electromagnetic signal for transmission, or converts the received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 404 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, and the like. The radio frequency circuit 404 can communicate with other terminals through at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: a metropolitan area network, various generations of mobile communication networks (2G, 3G, 4G and 5G), a wireless local area network and / or a WiFi (Wireless Fidelity) network. In some embodiments, the radio frequency circuit 404 may also include circuits related to NFC (NearField Communication), which is not limited in this application.

[0168] The display screen 405 is used to display the UI (User Interface). The UI may include graphics, text, icons, videos and any combination thereof. When the display screen 405 is a touch display screen, the display screen 405 also has the ability to collect touch signals on the surface or above the surface of the display screen 405. The touch signal can be input to the processor 401 as a control signal for processing. At this time, the display screen 405 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, the display screen 405 can be one, and the front panel of the terminal 400 is set; in other embodiments, the display screen 405 can be at least two, which are respectively set on different surfaces of the terminal 400 or are folded; in some other embodiments, the display screen 405 can be a flexible display screen, which is set on the curved surface or folded surface of the terminal 400. Even, the display screen 405 can also be set to a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 405 can be made of materials such as LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode, organic light-emitting diode).

[0169] The camera assembly 406 is used to capture images or videos. Optionally, the camera assembly 406 includes a front camera and a rear camera. Typically, the front camera is arranged on the front panel of the terminal, and the rear camera is arranged on the back of the terminal. In some embodiments, there are at least two rear cameras, which are any one of a main camera, a depth of field camera, a wide-angle camera, and a telephoto camera, so as to realize the fusion of the main camera and the depth of field camera to realize the background blur function, the fusion of the main camera and the wide-angle camera to realize the panoramic shooting and VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, the camera assembly 406 may also include a flash. The flash can be a monochrome temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cold light flash, which can be used for light compensation at different color temperatures.

[0170] The audio circuit 407 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, and convert the sound waves into electrical signals and input them into the processor 401 for processing, or input them into the radio frequency circuit 404 to achieve voice communication. For the purpose of stereo acquisition or noise reduction, there may be multiple microphones, which are respectively arranged at different parts of the terminal 400. The microphone may also be an array microphone or an omnidirectional acquisition microphone. The speaker is used to convert the electrical signal from the processor 401 or the radio frequency circuit 404 into sound waves. The speaker may be a traditional film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can not only convert the electrical signal into sound waves audible to humans, but also convert the electrical signal into sound waves inaudible to humans for purposes such as ranging. In some embodiments, the audio circuit 407 may also include a headphone jack.

[0171] Positioning component 408 is used to locate the current geographical location of terminal 400 to implement navigation or LBS (Location Based Service). Positioning component 408 can be a positioning component based on the US GPS (Global Positioning System), China's Beidou system, Russia's Grenas system or the European Union's Galileo system.

[0172] The power supply 409 is used to power various components in the terminal 400. The power supply 409 can be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 409 includes a rechargeable battery, the rechargeable battery can support wired charging or wireless charging. The rechargeable battery can also be used to support fast charging technology.

[0173] In some embodiments, the terminal 400 further includes one or more sensors 410 , including but not limited to: an acceleration sensor 411 , a gyroscope sensor 412 , a pressure sensor 413 , a fingerprint sensor 414 , an optical sensor 415 , and a proximity sensor 416 .

[0174] The acceleration sensor 411 can detect the magnitude of acceleration on the three coordinate axes of the coordinate system established by the terminal 400. For example, the acceleration sensor 411 can be used to detect the components of gravity acceleration on the three coordinate axes. The processor 401 can control the display screen 405 to display the user interface in a horizontal view or a vertical view according to the gravity acceleration signal collected by the acceleration sensor 411. The acceleration sensor 411 can also be used to collect game or user motion data.

[0175] The gyro sensor 412 can detect the body direction and rotation angle of the terminal 400, and the gyro sensor 412 can cooperate with the acceleration sensor 411 to collect the user's 3D actions on the terminal 400. The processor 401 can implement the following functions based on the data collected by the gyro sensor 412: motion sensing (such as changing the UI according to the user's tilt operation), image stabilization during shooting, game control, and inertial navigation.

[0176] The pressure sensor 413 can be set on the side frame of the terminal 400 and / or the lower layer of the display screen 405. When the pressure sensor 413 is set on the side frame of the terminal 400, it can detect the user's holding signal of the terminal 400, and the processor 401 performs left and right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 413. When the pressure sensor 413 is set on the lower layer of the display screen 405, the processor 401 controls the operability controls on the UI interface according to the user's pressure operation on the display screen 405. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

[0177] The fingerprint sensor 414 is used to collect the user's fingerprint, and the processor 401 identifies the user's identity based on the fingerprint collected by the fingerprint sensor 414, or the fingerprint sensor 414 identifies the user's identity based on the collected fingerprint. When the user's identity is identified as a trusted identity, the processor 401 authorizes the user to perform relevant sensitive operations, which include unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings. The fingerprint sensor 414 can be set on the front, back, or side of the terminal 400. When a physical button or a manufacturer logo is set on the terminal 400, the fingerprint sensor 414 can be integrated with the physical button or the manufacturer logo.

[0178] The optical sensor 415 is used to collect the ambient light intensity. In one embodiment, the processor 401 can control the display brightness of the display screen 405 according to the ambient light intensity collected by the optical sensor 415. Specifically, when the ambient light intensity is high, the display brightness of the display screen 405 is increased; when the ambient light intensity is low, the display brightness of the display screen 405 is decreased. In another embodiment, the processor 401 can also dynamically adjust the shooting parameters of the camera assembly 406 according to the ambient light intensity collected by the optical sensor 415.

[0179] The proximity sensor 416, also called a distance sensor, is usually disposed on the front panel of the terminal 400. The proximity sensor 416 is used to collect the distance between the user and the front of the terminal 400. In one embodiment, when the proximity sensor 416 detects that the distance between the user and the front of the terminal 400 is gradually decreasing, the processor 401 controls the display screen 405 to switch from the screen-on state to the screen-off state; when the proximity sensor 416 detects that the distance between the user and the front of the terminal 400 is gradually increasing, the processor 401 controls the display screen 405 to switch from the screen-off state to the screen-on state.

[0180] Those skilled in the art will understand that Figure 4 The structure shown in the figure does not constitute a limitation on the terminal 400, and the terminal 400 may include more or less components than those shown in the figure, or combine some components, or adopt a different component arrangement.

[0181] In an exemplary embodiment, a storage medium including a program code is also provided, such as a memory including the program code, and the program code can be executed by a processor of the device to complete the above method. Optionally, the storage medium can be a non-temporary computer-readable storage medium, for example, the non-temporary computer-readable storage medium can be a ROM (Read-Only Memory), a RAM (Random Access Memory), a CD-ROM (Compact Disc Read-Only Memory), a magnetic tape, a floppy disk, an optical data storage device, etc.

[0182] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining dynamic reserves, characterized in that: The method comprises: Obtain the pressure, temperature and production of the oil well to be tested; Determining a volume coefficient of crude oil in the oil well according to the temperature and the pressure, and determining a compressibility coefficient of the oil well; Obtaining the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well; According to the production, the volume coefficient, the compression coefficient, the flow velocity duration of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well, the change in the bottom hole pressure of the oil well is determined by the following formula three; Formula 3: Wherein, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well; According to the change in the bottom hole pressure and the flow time of the crude oil in the oil well, the first logarithmic value corresponding to the bottom hole pressure is determined by the following formula 6; and according to the production, the volume coefficient, the pore volume of the reservoir where the oil well is located, the compressibility coefficient of the oil well and the flow time of the crude oil in the oil well, the second logarithmic value corresponding to the change in the bottom hole pressure is determined by the following formula 7; Formula 6: Formula 7: Where M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in bottom hole pressure, q represents the production, B represents the volume coefficient of crude oil in the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well; The flow characteristics of the oil well are determined according to the first logarithmic value and the second logarithmic value, wherein the first logarithmic value and the second logarithmic value are the same and both are values ​​indicating that the flow stage of the oil well is a quasi-stable flow stage. The flow characteristics are used to indicate the flow stage of the oil well; When the flow characteristics are used to indicate that the flow stage of the oil well is a quasi-stable flow stage, determining a target production corresponding to when the oil well is in the quasi-stable flow stage; determining the volume of fracturing fluid in the oil well; Acquire the duration of the oil well being in the quasi-stable flow stage, and the change in bottom hole pressure of the oil well corresponding to the quasi-stable flow stage; The volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4 according to the duration, the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, the volume coefficient and the compressibility coefficient; Formula 4: Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of the crude oil in the oil well, C t represents the compression coefficient of the oil well, Δp represents the change in the bottom hole pressure of the oil well, and t represents the time length; The difference between the volume of crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid is determined as the dynamic reserve of the oil well.

2. The method according to claim 1, characterized in that Determining the volume coefficient of the crude oil in the oil well according to the temperature and the pressure includes: According to the temperature, determining a temperature coefficient matching the temperature; According to the temperature coefficient and the pressure, the volume coefficient of the crude oil in the oil well is determined by the following formula 1; Formula 1: B = 0.952-2.154×10 -4 P R +10 A Wherein, B represents the volume coefficient of crude oil in the oil well, P R represents the pressure, and A represents the temperature coefficient.

3. The method according to claim 1, characterized in that Determining the compression coefficient of the oil well includes: Obtaining the compressibility coefficient of the rock, the compressibility coefficient of the crude oil and the compressibility coefficient of water in the oil well; and determining the saturation of the crude oil and the saturation of water in the oil well; According to the compression coefficient of the rock, the compression coefficient of the crude oil, the compression coefficient of the water, the saturation of the crude oil and the saturation of the water, the compression coefficient of the oil well is determined by the following formula 2; Formula 2: C t =C r +C o S o +C w S w Among them, C t represents the compressibility factor of the oil well, C r represents the compressibility coefficient of the rock, C o represents the compressibility coefficient of the crude oil, C w represents the compressibility of water, S o Indicates the saturation of the crude oil, S w Indicates the saturation of the water.

4. A device for determining dynamic reserves, characterized in that: The device comprises: An acquisition module, used to acquire the pressure, temperature and production of the oil well to be tested; A first determination module, used to determine the volume coefficient of the crude oil in the oil well and the compressibility coefficient of the oil well according to the temperature and the pressure; The second determination module is used to obtain the flow time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well; according to the production, the volume coefficient, the compression coefficient, the flow rate time of the crude oil in the oil well, the viscosity of the crude oil, the bottom hole depth of the oil well, the bottom hole permeability of the oil well, the area of ​​the reservoir where the oil well is located, the pore volume of the reservoir where the oil well is located, the bottom hole resistance coefficient of the oil well, the shape factor of the oil well and the radius of the oil well, the change of the bottom hole pressure of the oil well is determined by the following formula three; Formula 3: Wherein, Δp represents the change in the bottom hole pressure of the oil well, q represents the production, μ represents the viscosity of the crude oil, B represents the volume coefficient, K represents the bottom hole permeability of the oil well, h represents the bottom hole depth of the oil well, A represents the area of ​​the reservoir where the oil well is located, S represents the bottom hole resistance coefficient of the oil well, r represents the radius of the oil well, and C A represents the shape factor of the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of the crude oil in the oil well; The second determination module is used to determine a first logarithmic value corresponding to the bottom hole pressure according to the change in the bottom hole pressure and the flow time of the crude oil in the oil well through the following formula 6, and to determine a second logarithmic value corresponding to the change in the bottom hole pressure according to the production, the volume coefficient, the pore volume of the reservoir where the oil well is located, the compressibility coefficient of the oil well and the flow time of the crude oil in the oil well through the following formula 7; Formula 6: Formula 7: Where M represents the first logarithmic value, N represents the second logarithmic value, Δp represents the change in bottom hole pressure, q represents the production, B represents the volume coefficient of crude oil in the oil well, V P represents the pore volume of the reservoir where the oil well is located, C t represents the compression coefficient of the oil well, and t represents the flow time of crude oil in the oil well; The second determination module is used to determine the flow characteristics of the oil well according to the first logarithmic value and the second logarithmic value, the first logarithmic value and the second logarithmic value are the same, and both are values ​​indicating that the flow stage of the oil well is a quasi-stable flow stage, and the flow characteristics are used to indicate the flow stage of the oil well; A third determination module is used to determine a target production corresponding to when the oil well is in the quasi-stable flow stage when the flow characteristic is used to indicate that the flow stage of the oil well is in the quasi-stable flow stage; The fourth determination module is used to determine the volume of the fracturing fluid in the oil well; obtain the time duration that the oil well is in the quasi-stable flow stage, and the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage; according to the time duration, the change in the bottom hole pressure of the oil well corresponding to the quasi-stable flow stage, the target production, the volume coefficient and the compression coefficient, the volume of crude oil in the pores of the reservoir where the oil well is located is determined by the following formula 4; Formula 4: Among them, V s represents the volume of crude oil in the pores of the reservoir where the oil well is located, q represents the target production, B represents the volume coefficient of the crude oil in the oil well, C t represents the compression coefficient of the oil well, Δp represents the change in the bottom hole pressure of the oil well, and t represents the time length; The fourth determination module is used to determine the difference between the volume of crude oil in the pores of the reservoir where the oil well is located and the volume of the fracturing fluid as the dynamic reserve of the oil well.

5. A computer device, characterized in that: The computer device comprises: A processor and a memory, wherein at least one program code is stored in the memory, and the at least one program code is loaded and executed by the processor to implement the operations performed in the dynamic reserve determination method according to any one of claims 1 to 3.

6. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the operations performed in the method for determining dynamic reserves according to any one of claims 1 to 3.

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