Determination Method, Device, Equipment and Storage Medium for Selecting Wells for Electrical Submersible Screw Pumps

Abstract

The present invention relates to the technical field of oil extraction, and particularly relates to a method, device, equipment and storage medium for determining an oil well selected for an electric submersible screw pump. The method includes: obtaining screw pump data according to the pump suction inlet pressure of the screw pump and the expected production of the oil well, wherein the pump suction inlet pressure is obtained based on the natural gas data, crude oil data and water cut data in the oil well, and the expected production is obtained based on the historical production and historical pressure of the oil well; obtaining motor data of the submersible motor according to the screw pump data; obtaining cable data of the submersible cable according to the oil well temperature and the motor data; obtaining cabinet data of the control cabinet according to the motor data, the cable data and the wellhead environment data of the oil well; and determining a report of the electric submersible screw pump matched with the oil well according to the screw pump data, the motor data, the cable data and the cabinet data. The method realizes the optimization of the selection of the electric submersible screw pump for the oil well, improves the applicability of the electric submersible screw pump, realizes the balance between oil well supply and production, and prolongs the pump inspection period of the oil well.

Description

Technical Field

[0001] The present invention relates to the technical field of oil extraction, and particularly relates to a method, device, equipment and storage medium for determining the selection of wells for electric submersible screw pumps. Background Art

[0002] Affected by various factors such as well trajectory, crude oil physical properties, and reservoir characteristics, the lifting method of rod pumps is bound to have the phenomenon of eccentric wear between the tubing and the rod. With the gradual deepening of oilfield development, phenomena such as increasing water cut, increasing crude oil viscosity, and aggravated eccentric wear will occur. These phenomena will cause the rod pumps to have problems such as pump jamming, rod jamming, pump wear, and sucker rod breakage and disconnection, resulting in frequent oil well operations or even production suspension. For example, the scrapping rate of rod pumps caused by the eccentric wear of tubing and rods in oilfields is gradually increasing.

[0003] In view of the disadvantages of rod pumps, electric submersible screw pumps are often used now. The lifting technology of electric submersible screw pumps is a rodless pump lifting technology. The downhole permanent magnet direct drive motor drives the downhole screw pump to pump the downhole crude oil to achieve crude oil lifting. Different from rod pumps, screw pumps rely on the sealed chamber formed by the rotor and the stator to lift crude oil, and have certain advantages in sand-carrying or mud-carrying oil production.

[0004] However, in the process of on-site application, affected by factors such as oil product properties, crude oil physical properties, and liquid supply capacity, there are currently no relevant standards and regulations to determine the selection of wells for electric submersible screw pumps. At present, it is still implemented according to the relevant designs of the original well pumping units, which will cause the problem of low utilization rate of electric submersible screw pump wells. Summary of the Invention

[0005] By providing a method, device, equipment and storage medium for determining the selection of wells for electric submersible screw pumps, the embodiments of the present application solve the technical problem of low utilization rate of electric submersible screw pump wells in the prior art, provide a basis for selecting wells for electric submersible screw pumps, improve the applicability of electric submersible screw pumps, achieve the balance of oil well supply and production, and extend the pump inspection period of oil wells.

[0006] In a first aspect, an embodiment of the present invention provides a method for determining the selection of wells for an electric submersible screw pump. The electric submersible screw pump includes a screw pump, a submersible motor, a submersible cable, and a control cabinet. The control cabinet is connected to the submersible motor through the submersible cable, and the submersible motor is also connected to the screw pump. The method is characterized in that it includes:

[0007] Obtain screw pump data according to the pump suction inlet pressure of the screw pump and the predicted production of the oil well, wherein the pump suction inlet pressure is obtained according to the natural gas data, crude oil data, and water cut data in the oil well, and the predicted production is obtained according to the historical production and historical pressure of the oil well;

[0008] Obtain motor data of the submersible motor according to the screw pump data;

[0009] Obtain the cable data of the submersible cable according to the oil well temperature and the motor data;

[0010] Obtain the cabinet data of the control cabinet according to the motor data, the cable data and the wellhead environment data of the oil well;

[0011] Determine the report of the electric submersible screw pump matching the oil well according to the screw pump data, the motor data, the cable data and the cabinet data.

[0012] Preferably, the step of obtaining the pump suction inlet pressure includes:

[0013] Measure a plurality of pump suction inlet pressure values through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected to the submersible motor;

[0014] Obtain the pump suction inlet gas-liquid ratio corresponding to each pump suction inlet pressure value according to the natural gas data, the crude oil data, the water content data and each pump suction inlet pressure value, and obtain the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio;

[0015] According to the target pump suction inlet gas-liquid ratio, find the pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio and determine it as the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range.

[0016] Preferably, the obtaining the pump suction inlet gas-liquid ratio corresponding to each pump suction inlet pressure value according to the natural gas data, the crude oil data, the water content data and each pump suction inlet pressure value, and obtaining the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio includes:

[0017] Obtain the saturated dissolved gas-oil ratio at the saturated pressure according to the relative density of natural gas in the natural gas data, the relative density of crude oil in the crude oil data, the saturated pressure in the crude oil data and the bottom hole temperature of the oil well;

[0018] Correct the saturated dissolved gas-oil ratio through a correction coefficient to obtain the corrected dissolved gas-oil ratio, wherein the correction coefficient is obtained according to the pump suction inlet pressure value and the saturated pressure;

[0019] Obtain the natural gas volume coefficient according to the pump setting depth temperature of the screw pump and the pump suction inlet pressure value;

[0020] Obtain the formation oil volume factor based on the relative density of the natural gas, the relative density of the crude oil, and the corrected gas-oil ratio of dissolution.

[0021] Obtain the corresponding gas-liquid ratio at the pump suction inlet based on the production gas-oil ratio, the water cut of the water cut data, the corrected gas-oil ratio of dissolution, the natural gas volume factor, the volume of the oil-gas-water mixture at the pump suction inlet of the progressing cavity pump, and the formation oil volume factor.

[0022] Obtain the corresponding relationship based on each of the suction inlet pressure values and the corresponding gas-liquid ratio at the pump suction inlet.

[0023] Preferably, the step of obtaining the predicted production includes:

[0024] Obtain the predicted production based on the formation pressure of the oil well, the bottom-hole flowing pressure of the oil well, and the oil well production in the historical production.

[0025] Preferably, the obtaining of the progressing cavity pump data based on the pump suction inlet pressure of the progressing cavity pump and the predicted production of the oil well includes:

[0026] Obtain the theoretical displacement of the progressing cavity pump based on the displacement per revolution of the progressing cavity pump and the rotational speed of the progressing cavity pump.

[0027] Obtain the actual production based on the theoretical displacement of the progressing cavity pump and the pump efficiency.

[0028] If the target actual production is not less than the predicted production, determine the theoretical displacement of the progressing cavity pump corresponding to the target actual production as the actual displacement of the progressing cavity pump.

[0029] Obtain the total dynamic head of the progressing cavity pump based on the pump setting depth of the progressing cavity pump, the head converted from the oil pressure, the head loss due to tubing friction, and the head converted from the pump suction inlet pressure.

[0030] If the target head is not less than the total dynamic head, determine the target head as the head of the progressing cavity pump, where the target head is the lifting height of the progressing cavity pump, and the progressing cavity pump data includes the head of the progressing cavity pump and the actual displacement of the progressing cavity pump.

[0031] Preferably, the obtaining of the submersible motor data based on the progressing cavity pump data includes:

[0032] Obtain the torque of the submersible motor based on the driving torque at zero head and the head of the progressing cavity pump.

[0033] Obtain the shaft power of the submersible motor based on the actual displacement of the progressing cavity pump, the head of the progressing cavity pump, the average relative density of the well fluid of the oil well, and the pump efficiency, where the motor data includes the torque of the submersible motor and the shaft power of the submersible motor.

[0034] Preferably, obtaining the cable data of the submersible cable according to the oil well temperature and the motor data includes:

[0035] Determining the model of the submersible cable according to the bottom hole temperature, the shaft power of the submersible motor, the voltage of the submersible motor, and the current of the submersible motor;

[0036] Determining the length of the submersible cable according to the pump setting depth;

[0037] Obtaining the voltage drop loss and power loss of the submersible cable according to the length of the submersible cable and the model of the submersible cable; wherein, the cable data includes the model of the submersible cable, the length of the submersible cable, the voltage drop loss of the submersible cable, and the power loss.

[0038] Based on the same inventive concept, in a second aspect, the present invention further provides a device for determining the selection of an electric submersible screw pump well. The electric submersible screw pump includes a screw pump, a submersible motor, a submersible cable, and a control cabinet. The control cabinet is connected to the submersible motor through the submersible cable, and the submersible motor is further connected to the screw pump. It is characterized in that the device includes:

[0039] A screw pump data module for obtaining screw pump data according to the pump suction pressure of the screw pump and the predicted production of the oil well, wherein the pump suction pressure is obtained according to the natural gas data, crude oil data, and water cut data in the oil well, and the predicted production is obtained according to the historical production and historical pressure of the oil well;

[0040] A motor data module for obtaining the motor data of the submersible motor according to the screw pump data;

[0041] A cable data module for obtaining the cable data of the submersible cable according to the oil well temperature and the motor data;

[0042] A cabinet data module for obtaining the cabinet data of the control cabinet according to the motor data, the cable data, and the wellhead environment data of the oil well;

[0043] A production module for determining a report of the electric submersible screw pump that matches the oil well according to the screw pump data, the motor data, the cable data, and the cabinet data.

[0044] Based on the same inventive concept, in a third aspect, the present invention provides a computer device, including a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the program, it implements the steps of the method for determining the selection of an electric submersible screw pump well.

[0045] Based on the same inventive concept, in a fourth aspect, the present invention provides a computer-readable storage medium, on which a computer program is stored, and when the program is executed by a processor, the steps of the method for determining the selection of an electric submersible screw pump well are implemented.

[0046] One or more technical solutions in the embodiments of the present invention have at least the following technical effects or advantages:

[0047] In the embodiments of the present application, through the collection of data such as natural gas data, crude oil data, water cut data, historical production of the oil well, and oil well pressure in the oil well, dynamic analysis is carried out to obtain screw pump data, motor data, cable data, and cabinet data, so as to determine the appropriate production allocation of the screw pump, submersible motor, submersible cable, and control cabinet, optimize the displacement and lift of the screw pump, determine the shaft power of the motor, electrical parameters such as cables and control cabinets, realize the optimized selection of electric submersible screw pump wells, improve the applicable performance of the electric submersible screw pump, achieve the balance between oil well supply and production, and extend the pump inspection period of the oil well. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] By reading the detailed description of the preferred embodiments below, various other advantages and benefits will become clear to those of ordinary skill in the art. The drawings are only for the purpose of showing the preferred embodiments and are not considered to be a limitation of the present invention. Moreover, throughout the drawings, the same reference numerals are used to represent the same components. In the drawings:

[0049] Figure 1 A schematic flow chart of the steps of the method for determining the selection of an electric submersible screw pump well in the embodiments of the present invention is shown;

[0050] Figure 2 A schematic structural diagram of the electric submersible screw pump in the embodiments of the present invention is shown;

[0051] Figure 3 A schematic module diagram of the device for determining the selection of an electric submersible screw pump well in the embodiments of the present invention is shown;

[0052] Figure 4 A schematic structural diagram of a computer device in the embodiments of the present invention is shown. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0053] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the drawings. Although the exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided so that the present disclosure can be more thoroughly understood and the scope of the present disclosure can be fully conveyed to those skilled in the art.

[0054] Embodiment 1

[0055] The first embodiment of the present invention provides a method for determining the selection of an electric submersible screw pump, which is applied to an electric submersible screw pump. In order to clearly introduce the method for determining the selection of an electric submersible screw pump, it is first necessary to introduce the structure of the electric submersible screw pump. As Figure 2 shown, the electric submersible screw pump includes: a downhole centralizer 201, a temperature and pressure measuring device 202, a submersible motor 203, a motor protector 204, a coupling 205, a screw pump 206, a submersible cable 207, a check valve 208, a drain valve 209, an electric pump wellhead 210, a junction box 211, and a control cabinet 212.

[0056] The downhole centralizer 201 is arranged at the lowest end of the screw pump 206, close to the oil layer. The downhole centralizer 201 is used for downhole centralization to eliminate the axial force during the rotation of the screw pump 206.

[0057] The temperature and pressure measuring device 202 is arranged above the downhole centralizer 201, and the temperature and pressure measuring device 202 is connected to the submersible motor 203. The temperature and pressure measuring device 202 is used to measure the bottom hole temperature and track the temperature rise change of the submersible motor 203 in real time; measure the bottom hole pressure and convert the oil well submergence pressure to avoid dry pumping of the screw pump 206.

[0058] The submersible motor 203 is arranged above the temperature and pressure measuring device 202 and below the motor protector 204. The submersible motor 203 is used to provide power for the rotation of the screw pump 206, and this power is concentric rotation. Among them, the motor protector 204 is used to provide motor oil expansion space for the submersible motor 203 when the submersible motor 203 heats up and cools down.

[0059] The coupling 205 is arranged between the submersible motor 203 and the screw pump 206; and one end of the coupling 205 is connected to the submersible motor 203, and the other end is connected to the screw pump 206. The coupling 205 is used to convert the concentric rotation of the submersible motor 203 into eccentric rotation of the screw pump 206.

[0060] The screw pump 206 is arranged above the coupling 205. The screw pump 206 is used to lift the crude oil to the ground through the screw pump 206.

[0061] The check valve 208 is arranged on the screw pump 206 and is used to prevent the liquid column and the sand-containing crude oil in the liquid column from entering the screw pump 206 during the shutdown process.

[0062] The drain valve 209 is arranged above the check valve 208 and is used to achieve environmental protection operations during the well pulling process.

[0063] The control cabinet 212 is set on the ground and is connected to the submersible motor 203 through the junction box 211 and the submersible cable 207. Among them, the control cabinet 212 is used for ground parameter adjustment equipment and provides electrical energy for the electric submersible screw pump. The junction box 211 is set on the ground to prevent the insulation impact of downhole gas on the control cabinet 212. The submersible cable 207 is used to transmit the ground electrical energy to the submersible motor 203 downhole.

[0064] After understanding the structure and principle of the electric submersible screw pump, the method for determining the well selection of the electric submersible screw pump will be introduced in detail. As Figure 1 shown, as Figure 1 shown, it includes:

[0065] S101, obtaining screw pump data according to the pump suction inlet pressure of the screw pump 206 and the expected production of the oil well, where the pump suction inlet pressure is obtained according to the natural gas data, crude oil data and water content data in the oil well, and the expected production is obtained according to the historical production and historical pressure of the oil well;

[0066] S102, obtaining the motor data of the submersible motor 203 according to the screw pump data;

[0067] S103, obtaining the cable data of the submersible cable 207 according to the oil well temperature and the motor data;

[0068] S104, obtaining the cabinet data of the control cabinet 212 according to the motor data, the cable data and the wellhead environment data of the oil well;

[0069] S105, determining the report of the electric submersible screw pump matching the oil well according to the screw pump data, the motor data, the cable data and the cabinet data.

[0070] It should be noted that relevant data is collected in the early stage of this method, such as natural gas data, crude oil data, water content data, historical production of the oil well and historical pressure of the oil well, etc. Historical production is data related to the produced liquid, including daily produced liquid, volume of crude oil in the daily produced liquid, water content in the volume of daily produced crude oil, volume of natural gas produced daily, etc. Historical pressure includes the formation pressure of the oil well, the bottom hole flowing pressure of the oil well, etc.

[0071] Through the collection of data such as natural gas data, crude oil data, water content data, historical production of the oil well and oil well pressure in the oil well, dynamic analysis is carried out to obtain screw pump data, motor data, cable data and cabinet data, so as to determine the appropriate production allocation of the screw pump 206, the submersible motor 203, the submersible cable 207 and the control cabinet 212, optimize the displacement and lift of the screw pump 206, determine the shaft power of the submersible motor 203, cable, control cabinet 212 and other electrical parameters, realize the optimal well selection of the electric submersible screw pump, improve the applicability of the electric submersible screw pump, achieve the balance of oil well supply and production, and extend the pump inspection period of the oil well.

[0072] Next, in combination with Figure 1 the following will introduce in detail the specific implementation steps of the method for determining the well selection of the electric submersible screw pump provided in this embodiment:

[0073] First, perform step S101 to obtain screw pump data based on the pump suction inlet pressure of the screw pump 206 and the predicted production of the oil well. Among them, the pump suction inlet pressure is obtained based on the natural gas data, crude oil data, and water cut data in the oil well, and the predicted production is obtained based on the historical production and historical pressure of the oil well.

[0074] In step S101, first, the pump suction inlet pressure of the screw pump 206 and the predicted production of the oil well need to be obtained, and then the screw pump data can be obtained based on the pump suction inlet pressure and the predicted production. It should be noted that the order of the process of obtaining the pump suction inlet pressure and the process of obtaining the predicted production can be swapped or carried out simultaneously.

[0075] Specifically, the process of obtaining the pump suction inlet pressure: Measure multiple pump suction inlet pressure values through the temperature and pressure measuring device 202, where the temperature and pressure measuring device 202 is connected to the submersible motor 203; obtain the pump suction inlet gas-liquid ratio corresponding to each pump suction inlet pressure value based on the natural gas data, crude oil data, water cut data, and each pump suction inlet pressure value, and obtain the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio; based on the target pump suction inlet gas-liquid ratio, find the pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio and determine it as the pump suction inlet pressure, where the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range.

[0076] Specifically, the temperature and pressure measuring device 202 will measure multiple pump suction inlet pressure values. Then, combine each pump suction inlet pressure value with the natural gas data, crude oil data, and water cut data to obtain the pump suction inlet gas-liquid ratio corresponding to each pump suction inlet pressure value. Then, based on each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio, obtain the corresponding relationship and make a corresponding relationship curve. Finally, screen out the target pump suction inlet gas-liquid ratio from multiple pump suction inlet gas-liquid ratios, and through the corresponding relationship, determine the pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio as the pump suction inlet pressure. Among them, the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range, and the gas-liquid ratio threshold range is usually 0 to 25%, or can be set according to actual needs.

[0077] In the embodiments of this specification, the three-phase flow of crude oil, natural gas and water downhole enters the progressing cavity pump 206, and the space occupied by the natural gas volume in the progressing cavity pump 206 will reduce the filling degree of the progressing cavity pump 206. Therefore, in order to improve the pump efficiency of the progressing cavity pump 206, determining a reasonable gas-liquid ratio at the pump suction inlet is of great significance for the operation of the progressing cavity pump 206 downhole.

[0078] In the embodiments of this specification, the process of calculating the gas-liquid ratio at each pump suction inlet pressure value and the corresponding relationship between each pump suction inlet pressure value and the corresponding gas-liquid ratio at the pump suction inlet includes:

[0079] First step, according to the relative density of natural gas in the natural gas data, the relative density of crude oil in the crude oil data, the saturation pressure in the crude oil data, and the bottom hole temperature of the oil well, obtain the saturated dissolved gas-oil ratio at the saturation pressure.

[0080] Specifically, through formula (1), obtain the dissolved gas-oil ratio at the saturation pressure;

[0081]

[0082] where, R sb is the saturated dissolved gas-oil ratio at the saturation pressure, m 3 / m 3 ; γ g is the relative density of natural gas; γ 0 is the relative density of crude oil; p b is the saturation pressure, MPa; t is the bottom hole temperature, °C.

[0083] Since during the pumping process of the electric submersible progressing cavity pump, the bottom hole flowing pressure is generally lower than the saturation pressure. Therefore, for the case where the bottom hole flowing pressure is lower than the saturation pressure, the calculated dissolved gas-oil ratio must be corrected to compensate for the situation where the bottom hole flowing pressure is lower than the saturation pressure.

[0084] Second step, after obtaining the dissolved gas-oil ratio at the saturation pressure, correct the saturated dissolved gas-oil ratio through a correction factor to obtain the corrected dissolved gas-oil ratio, where the correction factor is obtained according to the pump suction inlet pressure value and the saturation pressure.

[0085] Specifically, the ratio of the pump suction inlet pressure value to the saturation pressure, that is, through formula (2), obtain the correction factor;

[0086]

[0087] where, f c is the correction factor, p is the pump suction inlet pressure value, MPa.

[0088] Through formula (3), obtain the corrected dissolved gas-oil ratio;

[0089] R sp = R sb × f c (3);

[0090] Wherein, R sp is the corrected dissolved gas-oil ratio, m 3 / m 3 .

[0091] In the third step, according to the temperature at the pump setting depth and the pump suction pressure value of the progressing cavity pump 206, the coefficient of formation volume factor of natural gas is obtained.

[0092] Specifically, the coefficient of formation volume factor of natural gas is obtained through formula (4);

[0093]

[0094] Wherein, B g is the coefficient of formation volume factor of natural gas, m 3 / m 3 ; Z is the compressibility factor of natural gas, generally taken between 0.81 - 0.91; t b is the temperature at the pump setting depth, °C.

[0095] In the fourth step, according to the relative density of natural gas, the relative density of crude oil and the corrected dissolved gas-oil ratio, the coefficient of formation volume factor of reservoir crude oil is obtained.

[0096] Specifically, the coefficient of formation volume factor of reservoir crude oil refers to the ratio of the volume of unit volume of crude oil under formation conditions to its volume after complete degassing. The coefficient of formation volume factor of reservoir crude oil is obtained through formula (5).

[0097]

[0098] Wherein, B 0 is the coefficient of formation volume factor of reservoir crude oil.

[0099] In the fifth step, according to the production gas-oil ratio, the water cut of the water cut data, the corrected dissolved gas-oil ratio, the coefficient of formation volume factor of natural gas, the volume of the oil-gas-water mixture at the pump suction of the progressing cavity pump 206 and the coefficient of formation volume factor of reservoir crude oil, the corresponding gas-liquid ratio at the pump suction is obtained, wherein the production gas-oil ratio is the ratio of the volume of natural gas to the volume of crude oil in the historical production, and the volume of the oil-gas-water mixture at the pump suction is the volume of the mixture of crude oil, natural gas and water at the pump suction of the progressing cavity pump 206.

[0100] The gas-liquid ratio at the pump suction is derived from the ratio of the volume of natural gas at the pump suction to the total volume of the mixture of natural gas, crude oil and water at the pump suction. The specific derivation process is as follows:

[0101]

[0102] Among them, GLR is the gas-liquid ratio at the pump suction inlet, %; V g is the natural gas volume at the pump suction inlet, m 3 ; V 0 is the crude oil volume at the pump suction inlet, m 3 ; V w is the water volume at the pump suction inlet, m 3 ; V t is the volume of the oil-gas-water mixture at the pump suction inlet, that is, V t = V 0 + V g + V w .

[0103] Since substituting into formula (6), it is simplified to formula (7);

[0104]

[0105] Among them, f w is the water cut, %; GOR is the production gas-oil ratio, %.

[0106] It should be noted that the production gas-oil ratio GOR is the ratio of the natural gas volume to the crude oil volume in the historical production. For example, assuming that in the historical production, the daily production fluid of a single well is 10 m 3 , the water cut is 10%, and the daily production natural gas volume is 1000 m 3 , then the daily production crude oil volume is 9 m 3 , and the production gas-oil ratio is 9 / 1000. The production gas-oil ratio can be taken as the ratio of the average daily production crude oil volume to the average daily production natural gas volume, or the ratio of the average daily production crude oil volume in the past 3 months at the exploration site to the average daily production natural gas volume in the past 3 months, and can also be set according to actual needs.

[0107] Step 6, obtain the corresponding relationship according to each suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio.

[0108] Specifically, calculate the pump suction inlet gas-liquid ratio at different pump suction inlet pressure values, and make the corresponding relationship curve of the pump suction inlet pressure value and the pump suction inlet gas-liquid ratio. In order to improve the pump efficiency, usually take the pump suction inlet pressure value corresponding to the pump suction inlet gas-liquid ratio less than 25% as the pump suction inlet pressure, so as to prevent the natural gas separated from the crude oil from entering the pump and occupying the space of the screw pump 206 at certain specific pressures.

[0109] In the embodiments of this specification, the process of obtaining the predicted production includes: obtaining the predicted production according to the formation pressure of the oil well, the bottom hole flowing pressure of the oil well, and the oil well production in the historical production.

[0110] Specifically, when the bottom-hole pressure of the oil well is lower than the saturation pressure, the crude oil starts to degas, and the seepage in the formation is two-phase flow of crude oil and natural gas or three-phase flow of crude oil, natural gas, and water. Then, the relationship curve between the predicted production and the bottom-hole pressure will bend, and they all follow the following relationship:

[0111]

[0112] Among them, p R is the formation pressure, MPa; p wf is the bottom-hole flowing pressure, MPa; q is the production of the oil well, m 3 / d; q max is the predicted production, and also the maximum production, m 3 / d.

[0113] It should be noted that the production q of the oil well can be the average value of the daily produced fluid in the historical production, or the average value of the daily produced fluid in the past 3 months, or can also be set according to the actual situation.

[0114] According to formula (8), draw the IPR curve (Inflow Performance Relationship Curve), and determine the predicted production at the bottom-hole flowing pressure. In this way, the predicted production can be planned reasonably and reliably, providing a solid foundation for screening the screw pump 206, the submersible motor 203, etc.

[0115] After obtaining the pump suction pressure and the predicted production of the oil well, obtain the screw pump data, so as to screen the type of the screw pump 206. Among them, the screw pump data includes the actual displacement and the head of the screw pump 206. The process of obtaining the screw pump data is as follows:

[0116] The first step is to determine the displacement of the screw pump 206.

[0117] Specifically, the theoretical displacement of the screw pump can be obtained according to the displacement per revolution of the screw pump and the rotational speed of the screw pump; the actual production can be obtained according to the theoretical displacement of the screw pump and the pump efficiency; if the target actual production is not less than the predicted production, the theoretical displacement of the screw pump corresponding to the target actual production is determined as the actual displacement of the screw pump.

[0118] Specifically, the actual displacement of the screw pump 206 is deduced according to the predicted production, so that the screw pump 206 meets the displacement requirements of the oil well. The screw pump 206 is an adjustable-speed operation pump, and the theoretical displacement of the screw pump is calculated by the following formula:

[0119] Q = 1440 × q b × n × 10 -6 (9);

[0120] Among them, Q is the theoretical displacement of the screw pump, m 3 / d; q b where q is the displacement per revolution of the screw pump, in ml / r; and n is the rotational speed of the screw pump, in r / min.

[0121] The actual production is calculated by the following formula:

[0122] Q fact = Q × η (10); where Q fact is the actual production, and η is the pump efficiency of the screw pump 206 at the pump setting depth, in %.

[0123] In view of the leakage during the operation of the screw pump 206 due to different submergence pressures, there is a pump efficiency problem. After the expected production is determined, it is necessary to satisfy the condition of Q × η ≥ q max to meet the requirements of the oil production unit. Therefore, when Q fact ≥ q max Q is determined as the actual displacement of the screw pump 206. fact

[0124] Step 2: Determine the lift of the screw pump 206.

[0125] Specifically, the total dynamic head of the screw pump 206 can be obtained based on the pump setting depth of the screw pump 206, the head converted from the oil pressure, the head loss due to tubing friction, and the head converted from the pump suction pressure. If the target lift is not less than the total dynamic head, then the target lift is determined as the lift of the screw pump 206, where the target lift is the lifting height of the screw pump 206.

[0126] Specifically, to ensure that the electrical submersible screw pump can lift the crude oil to the ground, it is necessary to overcome the total dynamic head, that is, Hs ≥ H. Where Hs is the lift of the screw pump 206, and H is the total dynamic head of the screw pump 206. The total dynamic head is calculated according to the following formula:

[0127] H = H d + p o + F t - p p (11);

[0128] where H is the total dynamic head of the screw pump 206, in m; H d is the pump setting depth, in m; p o is the head converted from the oil pressure, in m; F t is the head loss due to tubing friction, in m; p p is the head converted from the pump suction pressure, in m.

[0129] When the target lift is not less than the total dynamic head, it also indicates that the minimum value of the target lift is equal to the total dynamic head, then the target lift is determined as the lift of the screw pump 206.

[0130] ​In the embodiments of this specification, the screw pump 206 is divided into a rubber screw pump and a full-metal screw pump. The single-stage head of a normal rubber screw pump is 500 m, and the single-stage pressure bearing of a metal screw pump is 300 m. Therefore, the head (number of stages) of the rubber screw pump can be determined by the following formula:

[0131]

[0132] where L is the number of stages of the rubber screw pump, and H is the total dynamic head.

[0133] In this step, the screw pump data is obtained based on the pump suction pressure and the expected production, providing a reliable and accurate basis for selecting a suitable type of screw pump 206.

[0134] After obtaining the screw pump data, step S102 is executed. According to the screw pump data, the motor data of the submersible motor 203 is obtained, where the motor data includes the torque of the submersible motor 203 and the shaft power of the submersible motor 203.

[0135] Specifically, according to the screw pump data, the type of the submersible motor 203 is determined. Further, the torque and shaft power of the submersible motor 203 need to be determined. The process of obtaining the motor data is as follows:

[0136] The first step is to determine the torque of the submersible motor 203.

[0137] Specifically, the screw pump 206 realizes crude oil lifting by rotation. Therefore, the torque of the submersible motor 203 must be greater than the torque corresponding to the minimum head of the screw pump 206. Then, according to the driving torque under zero head and the head of the screw pump 206, the torque of the submersible motor 203 is obtained. The torque characteristic curve of the submersible motor 203 is an approximate curve that increases with the increase of pressure and is calculated according to the following formula:

[0138] M = M 0 + a·H s (13);

[0139] where M is the torque of the submersible motor 203, N·m; M 0 is the driving torque under zero head, N·m; a is the torque coefficient per unit lifting head of the screw pump, N·m / MPa.

[0140] In the embodiments of this specification, for the selected submersible motor 203 under the specified pump setting, it is necessary to select the torque M' of the submersible motor 203 such that M' ≥ M.

[0141] The second step is to determine the shaft power of the submersible motor 203.

[0142] Specifically, the progressive cavity pump 206 can be used to lift crude oil according to the pump setting depth of the oil well. The shaft power of the submersible motor 203 is obtained based on the actual displacement of the progressive cavity pump 206, the lift of the progressive cavity pump 206, the average relative density of the well fluid, and the pump efficiency. The specific formula is as follows:

[0143]

[0144] Wherein, N is the shaft power of the submersible motor 203 during the lifting process, in KW; γ 1 is the average relative density of the well fluid.

[0145] Specifically, the power of the motor protector 204 supporting the submersible motor 203 also needs to be considered. Therefore, 1.5 KW needs to be added to the submersible motor 203. Thus, the power of the submersible motor 203 is: (N + 1.5) KW. At the same time, in order to meet the requirements of special well conditions (such as sand production and pump jamming, wax deposition and blockage, etc.), the shaft power of the submersible motor 203 calculated needs to be increased by a safety factor of 1.5 times, that is, (N + 1.5) × 1.5 KW is used as the preferred rated power of the submersible motor 203.

[0146] This step fully considers and utilizes the progressive cavity pump data to design the submersible motor 203 data to ensure the reliability and accuracy of the motor data.

[0147] After obtaining the motor data, step S103 is executed. According to the oil well temperature and the motor data, the cable data of the submersible cable 207 is obtained. The cable data includes the model of the submersible cable 207, the length of the submersible cable 207, the voltage drop loss of the submersible cable 207, and the power loss of the submersible cable 207.

[0148] Specifically, according to the bottom hole temperature, the shaft power of the submersible motor 203, the voltage of the submersible motor 203, and the current of the submersible motor 203, the model of the submersible cable 207 is determined. For example, for the submersible motor of the brand Aote Pump Industry, its serial numbers are: 375, 456, 540, 562, 738; the national standard model is: YQY; the outer diameter is: 98, 116, 143, 188, with the unit of mm; the rated voltage is: 380V - 3000V; the rated frequency is: 50HZ (60HZ can be customized); the power range of 50HZ is: 4.7KW - 1008KW; the power range of 60HZ is 7.5 - 1620HP; the motor structure is: single-section, double-section, three-section.

[0149] Specifically, the length of the submersible cable 207 can be determined according to the pump setting depth, indicating that the length of the submersible cable 207 is not less than the pump setting depth.

[0150] Specifically, since there are voltage drop losses and power losses in any cable, the voltage drop loss and power loss of the submersible cable 207 can be determined according to the length and model of the submersible cable 207. The voltage drop loss and power loss of the submersible cable 207 are calculated by the following formulas:

[0151]

[0152] Where, △U is the cable voltage drop loss, V; sinφ is the reactive power coefficient; I is the rated current of the submersible motor 203, A; cosφ is the power factor; L c is the cable length, that is, the pump setting depth, m; R is the internal resistance of the submersible cable 207, Ω; r is the effective impedance of the conductor, Ω / km; X is the reactance of the conductor, Ω / km.

[0153] ΔP = 3I 2 R × 10 -3 (16);

[0154] Where, △P is the power loss of the submersible cable 207, kW.

[0155] Next, perform step S104 to obtain the cabinet data of the control cabinet 212 according to the motor data, cable data, and wellhead environment data of the oil well.

[0156] It should be explained that the wellhead environment data includes: the geographical location of the wellhead, the weather at the wellhead, the size of the wellhead area, the key equipment for reinjection and safe production at the wellhead, the casing head, the tubing head, and the Christmas tree, etc.

[0157] Specifically, the control cabinet 212 needs to consider the voltage drop loss and power loss of the submersible cable 207 to ensure that electrical energy can be sent to the submersible motor 203 to start the submersible motor 203; it should also be selected according to the wellhead environment data, on-site use conditions, and unit performance requirements. The control cabinet 212 mainly selects the capacity of the control cabinet 212 according to the rated current of the submersible motor 203 and the voltage required on the ground. The control cabinet 212 has the function of adjusting the power frequency in real time, so as to adjust the speed of the downhole unit and achieve the balance of oil well supply and production.

[0158] Finally, perform step S105 to determine the report of the electric submersible progressing cavity pump that matches the oil well according to the progressing cavity pump data, motor data, cable data, and cabinet data.

[0159] Specifically, according to the progressing cavity pump data, motor data, cable data, and cabinet data, generate an electronic or paper report of the electric submersible progressing cavity pump that matches the oil well, so that the relevant petroleum personnel can review it, and then carry out construction and oil production according to this reliable report.

[0160] One or more technical solutions in the embodiments of the present invention have at least the following technical effects or advantages:

[0161] Through the collection of data such as natural gas data, crude oil data, water cut data, historical production of the oil well, and oil well pressure in the oil well, dynamic analysis is carried out to obtain screw pump data, motor data, cable data, and cabinet data, so as to determine the appropriate production allocation of the screw pump, submersible motor, submersible cable, and control cabinet, optimize the displacement and lift of the screw pump, determine the shaft power of the motor, electrical parameters such as cables and control cabinets, realize the optimized well selection of the electric submersible screw pump, improve the applicable performance of the electric submersible screw pump, achieve the balance of oil well supply and production, and extend the pump inspection period of the oil well.

[0162] Embodiment Two

[0163] Based on the same inventive concept, the second embodiment of the present invention also provides a determination device for the well selection of an electric submersible screw pump, as Figure 3 shown, including:

[0164] A screw pump data module 301, configured to obtain screw pump data according to the suction inlet pressure of the screw pump and the expected production of the oil well, wherein the suction inlet pressure is obtained according to the natural gas data, crude oil data, and water cut data in the oil well, and the expected production is obtained according to the historical production and historical pressure of the oil well;

[0165] A motor data module 302, configured to obtain motor data of the submersible motor according to the screw pump data;

[0166] A cable data module 303, configured to obtain cable data of the submersible cable according to the oil well temperature and the motor data;

[0167] A cabinet data module 304, configured to obtain cabinet data of the control cabinet according to the motor data, the cable data, and the wellhead environment data of the oil well;

[0168] A production module 305, configured to determine a report of the electric submersible screw pump matching the oil well according to the screw pump data, the motor data, the cable data, and the cabinet data.

[0169] As an optional embodiment, the screw pump data module 301 is further configured to obtain the suction inlet pressure, and the obtaining step includes:

[0170] Measuring a plurality of suction inlet pressure values through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected to the submersible motor;

[0171] Based on the natural gas data, the crude oil data, the water content data, and each of the pump suction inlet pressure values, obtain the pump suction inlet gas-liquid ratio corresponding to each of the pump suction inlet pressure values, and obtain the corresponding relationship between each of the pump suction inlet pressure values and the corresponding pump suction inlet gas-liquid ratio;

[0172] Based on the target pump suction inlet gas-liquid ratio, from the corresponding relationship between each of the pump suction inlet pressure values and the corresponding pump suction inlet gas-liquid ratio, find the pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio and determine it as the pump suction inlet pressure, where the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range.

[0173] As an alternative embodiment, the obtaining the pump suction inlet gas-liquid ratio corresponding to each of the pump suction inlet pressure values and obtaining the corresponding relationship between each of the pump suction inlet pressure values and the corresponding pump suction inlet gas-liquid ratio according to the natural gas data, the crude oil data, the water content data, and each of the pump suction inlet pressure values includes:

[0174] Based on the relative density of natural gas in the natural gas data, the relative density of crude oil in the crude oil data, the saturation pressure in the crude oil data, and the bottom hole temperature of the oil well, obtain the saturated dissolved gas-oil ratio at the saturation pressure;

[0175] Correct the saturated dissolved gas-oil ratio through a correction coefficient to obtain the corrected dissolved gas-oil ratio, where the correction coefficient is obtained based on the pump suction inlet pressure value and the saturation pressure;

[0176] Based on the temperature at the pump setting depth of the progressing cavity pump and the pump suction inlet pressure value, obtain the natural gas volume coefficient;

[0177] Based on the relative density of natural gas, the relative density of crude oil, and the corrected dissolved gas-oil ratio, obtain the formation crude oil volume coefficient;

[0178] Based on the production gas-oil ratio, the water cut of the water content data, the corrected dissolved gas-oil ratio, the natural gas volume coefficient, the volume of the oil-gas-water mixture at the pump suction inlet of the progressing cavity pump, and the formation crude oil volume coefficient, obtain the corresponding pump suction inlet gas-liquid ratio;

[0179] Based on each of the suction inlet pressure values and the corresponding pump suction inlet gas-liquid ratio, obtain the corresponding relationship.

[0180] As an alternative embodiment, the progressing cavity pump data module 301 is further configured to obtain the predicted production, and the obtaining steps include:

[0181] Based on the formation pressure of the oil well, the bottom hole flowing pressure of the oil well, and the oil well production in the historical production, obtain the predicted production.

[0182] As an alternative embodiment, obtaining screw pump data according to the pump suction inlet pressure of the screw pump and the expected production of the oil well includes:

[0183] Obtaining the theoretical displacement of the screw pump according to the displacement per revolution of the screw pump and the rotational speed of the screw pump;

[0184] Obtaining the actual production according to the theoretical displacement of the screw pump and the pump efficiency;

[0185] If the target actual production is not less than the expected production, determining the theoretical displacement of the screw pump corresponding to the target actual production as the actual displacement of the screw pump;

[0186] Obtaining the total dynamic head of the screw pump according to the pump setting depth of the screw pump, the head converted from the oil pressure, the head loss due to tubing friction, and the head converted from the pump suction inlet pressure;

[0187] If the target head is not less than the total dynamic head, determining the target head as the head of the screw pump, where the target head is the lifting height of the screw pump, and the screw pump data includes the head of the screw pump and the actual displacement of the screw pump.

[0188] As an alternative embodiment, obtaining the motor data of the submersible motor according to the screw pump data includes:

[0189] Obtaining the torque of the submersible motor according to the driving torque at zero head and the head of the screw pump;

[0190] Obtaining the shaft power of the submersible motor according to the actual displacement of the screw pump, the head of the screw pump, the average relative density of the well fluid in the oil well, and the pump efficiency, where the motor data includes the torque of the submersible motor and the shaft power of the submersible motor.

[0191] As an alternative embodiment, obtaining the cable data of the submersible cable according to the oil well temperature and the motor data includes:

[0192] Determining the model of the submersible cable according to the bottom hole temperature, the shaft power of the submersible motor, the voltage of the submersible motor, and the current of the submersible motor;

[0193] Determining the length of the submersible cable according to the pump setting depth;

[0194] Obtaining the pressure drop loss and power loss of the submersible cable according to the length of the submersible cable and the model of the submersible cable; where the cable data includes the model of the submersible cable, the length of the submersible cable, the pressure drop loss of the submersible cable, and the power loss of the submersible cable.

[0195] Since the device for determining the well selection of the electrical submersible screw pump introduced in this embodiment is the device adopted for implementing the method for determining the well selection of the electrical submersible screw pump in Embodiment 1 of the present application, based on the method for determining the well selection of the electrical submersible screw pump introduced in Embodiment 1 of the present application, those skilled in the art can understand the specific implementation manners and various variations of the device for determining the well selection of the electrical submersible screw pump in this embodiment. Therefore, the implementation of how the device for determining the well selection of the electrical submersible screw pump realizes the method in Embodiment 1 of the present application will not be described in detail here. As long as those skilled in the art implement the device adopted for the method for determining the well selection of the electrical submersible screw pump in Embodiment 1 of the present application, it falls within the scope protected by the present application.

[0196] Embodiment 3

[0197] Based on the same inventive concept, the third embodiment of the present invention further provides a computer device, as Figure 4 shown, including a memory 404, a processor 402, and a computer program stored on the memory 404 and executable on the processor 402. When the processor 402 executes the program, it implements the steps of any one of the methods for determining the well selection of the electrical submersible screw pump described above.

[0198] Among them, in Figure 4 the bus architecture (represented by bus 400), bus 400 may include any number of interconnected buses and bridges. Bus 400 links together various circuits including one or more processors represented by processor 402 and a memory represented by memory 404. Bus 400 can also link together various other circuits such as peripheral devices, voltage regulators, and power management circuits, which are well known in the art. Therefore, they will not be further described herein. Bus interface 406 provides an interface between bus 400 and receiver 401 and transmitter 403. Receiver 401 and transmitter 403 can be the same element, that is, a transceiver, providing a unit for communicating with various other devices on the transmission medium. Processor 402 is responsible for managing bus 400 and general processing, while memory 404 can be used to store data used by processor 402 when performing operations.

[0199] Embodiment 4

[0200] Based on the same inventive concept, the fourth embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored. When the program is executed by a processor, it implements the steps of any one of the methods for determining the well selection of the electrical submersible screw pump described in the foregoing Embodiment 1.

[0201] Those skilled in the art will understand that the embodiments of the present invention can be provided as a method, a system, or a computer program product. Therefore, the present invention can take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present invention can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that contain computer-usable program code.

[0202] The present invention is described with reference to the flowcharts and / or block diagrams of methods, apparatuses (systems), and computer program products according to embodiments of the present invention. It should be understood that each flow and / or block in the flowchart and / or block diagram, as well as the combination of flows and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to the processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing devices to generate a machine, such that the instructions executed by the processor of the computer or other programmable data processing devices generate means for implementing the functions specified in one Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0203] These computer program instructions can also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to work in a specific manner, such that the instructions stored in the computer-readable memory generate a manufactured article including instruction means that implement the functions specified in one Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0204] These computer program instructions can also be loaded onto a computer or other programmable data processing device, such that a series of operation steps are executed on the computer or other programmable device to generate a computer-implemented process, and thus the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0205] Although the preferred embodiments of the present invention have been described, those skilled in the art can make additional changes and modifications once they learn the basic creative concepts. Therefore, the appended claims are intended to be construed to include the preferred embodiments as well as all changes and modifications that fall within the scope of the present invention.

[0206] Obviously, those skilled in the art can make various modifications and variations to the present invention without departing from the spirit and scope of the present invention. Thus, if these modifications and variations of the present invention fall within the scope of the claims of the present invention and their equivalent technologies, the present invention also intends to include these modifications and variations.

Claims

1. A method for determining well selection of an electrical submersible screw pump, which is applied to an electrical submersible screw pump. The electrical submersible screw pump includes a screw pump, a submersible motor, a submersible cable, and a control cabinet. The control cabinet is connected to the submersible motor through the submersible cable, and the submersible motor is also connected to the screw pump. Characterized in that, The method includes: Obtaining screw pump data according to the pump suction inlet pressure of the screw pump and the predicted production of the oil well, wherein the pump suction inlet pressure is obtained according to natural gas data, crude oil data, and water cut data in the oil well, and the predicted production is obtained according to the historical production and historical pressure of the oil well; Obtaining motor data of the submersible motor according to the screw pump data; Obtaining cable data of the submersible cable according to the oil well temperature and the motor data; Obtaining cabinet data of the control cabinet according to the motor data, the cable data, and the wellhead environment data of the oil well; Determining a report of the electrical submersible screw pump matching the oil well according to the screw pump data, the motor data, the cable data, and the cabinet data; The step of obtaining the pump suction inlet pressure includes: Measuring a plurality of pump suction inlet pressure values through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected to the submersible motor; Obtaining the pump suction inlet gas-liquid ratio corresponding to each pump suction inlet pressure value according to the natural gas data, the crude oil data, the water cut data, and each pump suction inlet pressure value, and obtaining the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio; Including: Obtaining the saturated dissolved gas-oil ratio at the saturated pressure according to the relative density of natural gas in the natural gas data, the relative density of crude oil in the crude oil data, the saturated pressure in the crude oil data, and the bottom hole temperature of the oil well; Correcting the saturated dissolved gas-oil ratio through a correction coefficient to obtain a corrected dissolved gas-oil ratio, wherein the correction coefficient is obtained according to the pump suction inlet pressure value and the saturated pressure; Obtaining the natural gas volume coefficient according to the temperature at the pump setting depth of the screw pump and the pump suction inlet pressure value; Obtaining the oil layer crude oil volume coefficient according to the relative density of natural gas, the relative density of crude oil, and the corrected dissolved gas-oil ratio; Obtaining the corresponding pump suction inlet gas-liquid ratio according to the production gas-oil ratio, the water cut rate of the water cut data, the corrected dissolved gas-oil ratio, the natural gas volume coefficient, the volume of the oil-gas-water mixture at the pump suction inlet of the screw pump, and the oil layer crude oil volume coefficient; Obtaining the corresponding relationship according to each suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio; According to the target pump suction inlet gas-liquid ratio, finding the pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relationship between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio and determining it as the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range.

2. The method according to claim 1, Characterized in that, The step of obtaining the predicted production includes: Obtain the predicted production based on the formation pressure of the oil well, the bottom-hole flowing pressure of the oil well, and the oil well production in the historical production.

3. The method according to claim 2, wherein, obtaining the progressing cavity pump data based on the pump suction inlet pressure of the progressing cavity pump and the predicted production of the oil well includes: obtaining the theoretical displacement of the progressing cavity pump according to the displacement per revolution of the progressing cavity pump and the rotational speed of the progressing cavity pump; obtaining the actual production according to the theoretical displacement of the progressing cavity pump and the pump efficiency; if the target actual production is not less than the predicted production, determining the theoretical displacement of the progressing cavity pump corresponding to the target actual production as the actual displacement of the progressing cavity pump; obtaining the total dynamic head of the progressing cavity pump according to the pump setting depth of the progressing cavity pump, the head converted from the oil pressure, the head loss due to tubing friction, and the head converted from the pump suction inlet pressure; if the target lift is not less than the total dynamic head, determining the target lift as the lift of the progressing cavity pump, wherein the target lift is the lifting height of the progressing cavity pump, and the progressing cavity pump data includes the lift of the progressing cavity pump and the actual displacement of the progressing cavity pump.

4. The method according to claim 3, wherein, obtaining the submersible motor data based on the progressing cavity pump data includes: obtaining the torque of the submersible motor according to the driving torque under zero head and the lift of the progressing cavity pump; obtaining the shaft power of the submersible motor according to the actual displacement of the progressing cavity pump, the lift of the progressing cavity pump, the average relative density of the well fluid of the oil well, and the pump efficiency, wherein the submersible motor data includes the torque of the submersible motor and the shaft power of the submersible motor.

5. The method according to claim 4, wherein, obtaining the submersible cable data based on the oil well temperature and the submersible motor data includes: determining the model of the submersible cable according to the bottom-hole temperature, the shaft power of the submersible motor, the voltage of the submersible motor, and the current of the submersible motor; determining the length of the submersible cable according to the pump setting depth; obtaining the voltage drop loss and power loss of the submersible cable according to the length of the submersible cable and the model of the submersible cable; wherein the submersible cable data includes the model of the submersible cable, the length of the submersible cable, the voltage drop loss of the submersible cable, and the power loss of the submersible cable.

6. A determining device for selecting a well for an electric submersible progressing cavity pump, which is applied to an electric submersible progressing cavity pump. The electric submersible progressing cavity pump includes a progressing cavity pump, a submersible motor, a submersible cable, and a control cabinet. The control cabinet is connected to the submersible motor through the submersible cable, and the submersible motor is also connected to the progressing cavity pump. wherein, the device includes: a progressing cavity pump data module, configured to obtain progressing cavity pump data according to the pump suction inlet pressure of the progressing cavity pump and the predicted production of the oil well, wherein the pump suction inlet pressure is obtained according to the natural gas data, crude oil data, and water cut data in the oil well, and the predicted production is obtained according to the historical production and historical pressure of the oil well; the progressing cavity pump data module is further configured to: measure a plurality of pump suction inlet pressure values through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected to the submersible motor; Based on the natural gas data, the crude oil data, the water content data, and each of the pump suction inlet pressure values, obtain the gas-liquid ratio at the pump suction inlet corresponding to each of the pump suction inlet pressure values, and obtain the corresponding relationship between each of the pump suction inlet pressure values and the corresponding gas-liquid ratio at the pump suction inlet; Based on the target gas-liquid ratio at the pump suction inlet, from the corresponding relationship between each of the pump suction inlet pressure values and the corresponding gas-liquid ratio at the pump suction inlet, find the pump suction inlet pressure value corresponding to the target gas-liquid ratio at the pump suction inlet and determine it as the pump suction inlet pressure, where the target gas-liquid ratio at the pump suction inlet is within the gas-liquid ratio threshold range; The progressing cavity pump data module is further configured to: Based on the relative density of natural gas in the natural gas data, the relative density of crude oil in the crude oil data, the saturation pressure in the crude oil data, and the bottom hole temperature of the oil well, obtain the saturated dissolved gas-oil ratio at the saturation pressure; Through a correction coefficient, correct the saturated dissolved gas-oil ratio to obtain the corrected dissolved gas-oil ratio, where the correction coefficient is obtained based on the pump suction inlet pressure value and the saturation pressure; Based on the temperature at the pump setting depth of the progressing cavity pump and the pump suction inlet pressure value, obtain the natural gas volume coefficient; Based on the relative density of natural gas, the relative density of crude oil, and the corrected dissolved gas-oil ratio, obtain the formation crude oil volume coefficient; Based on the production gas-oil ratio, the water cut of the water content data, the corrected dissolved gas-oil ratio, the natural gas volume coefficient, the volume of the oil-gas-water mixture at the pump suction inlet of the progressing cavity pump, and the formation crude oil volume coefficient, obtain the corresponding gas-liquid ratio at the pump suction inlet; Based on each of the suction inlet pressure values and the corresponding gas-liquid ratio at the pump suction inlet, obtain the corresponding relationship; The motor data module is configured to obtain the motor data of the submersible motor based on the progressing cavity pump data; The cable data module is configured to obtain the cable data of the submersible cable based on the oil well temperature and the motor data; The control cabinet data module is configured to obtain the control cabinet data of the control cabinet based on the motor data, the cable data, and the wellhead environment data of the oil well; The production module is configured to determine the report of the electric submersible progressing cavity pump matching the oil well based on the progressing cavity pump data, the motor data, the cable data, and the control cabinet data.

7. The device according to claim 6, wherein, the progressing cavity pump data module is further configured to: Based on the formation pressure of the oil well, the bottom hole flowing pressure of the oil well, and the oil well production in the historical production, obtain the predicted production; 8. The device according to claim 7, wherein, the progressing cavity pump data module is further configured to: Based on the displacement per revolution of the progressing cavity pump and the rotational speed of the progressing cavity pump, obtain the theoretical displacement of the progressing cavity pump; Based on the theoretical displacement of the progressing cavity pump and the pump efficiency, obtain the actual production; If the target actual production is not less than the predicted production, then determine the theoretical displacement of the progressing cavity pump corresponding to the target actual production as the actual displacement of the progressing cavity pump; Based on the pump setting depth of the progressing cavity pump, the head converted from the oil pressure, the head loss due to tubing friction, and the head converted from the pump suction inlet pressure, obtain the total dynamic head of the progressing cavity pump. If the target head is not less than the total dynamic head, determine the target head as the head of the screw pump, where the target head is the lifting height of the screw pump, and the screw pump data includes the head of the screw pump and the actual displacement of the screw pump.

9. A computer device, comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, wherein, when the processor executes the program, the method steps described in any one of claims 1-5 are implemented.

10. A computer-readable storage medium, on which a computer program is stored, wherein, when the program is executed by the processor, the method steps described in any one of claims 1-5 are implemented.

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