Lifting system parameter acquisition method, device, equipment and storage medium

Abstract

The present application provides a method, device, equipment and storage medium for obtaining parameters of a lifting system, which obtain a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between the tubing pressure and the pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between the casing pressure and the pump hanging depth. According to the first mapping relationship and the second mapping relationship, the alternative parameters of the gas lift valve are determined. According to the alternative parameters of the gas lift valve, the first inlet pressure of the electric submersible pump is determined. If the difference between the first inlet pressure and the second inlet pressure is within the error range, the alternative parameters of the gas lift valve are used as the target parameters. Among them, the second inlet pressure is the inlet pressure of the electric submersible pump when there is no gas lift valve. From an engineering perspective, the parameters of the combined lifting system are optimized and designed to improve the stability of the system and the lifting efficiency of the system.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas production, and proposes a method, device, equipment and storage medium for obtaining parameters of a lifting system. Background Art

[0002] In recent years, the oil and gas fields in Tarim Oilfield that have been put into development have a large amount of natural gas coexisting with crude oil. In response to the lifting problem of such high gas-liquid ratio oil wells, electric submersible pump oil production and gas lift oil production have gradually revealed their own shortcomings.

[0003] The existing gas lift and electric submersible pump combined lifting system selects different lifting modes such as self-flowing, gas lift, electric pump lift, and electric pump and gas lift coupling lifting according to the changes in reservoir energy during the oil well production stage through coupling analysis or mathematical modeling, so as to avoid and overcome the technical defects of gas lift oil production and electric submersible pump oil production and give full play to their respective technical advantages.

[0004] However, the above-mentioned gas lift and electric submersible pump combined lifting system is not designed from an engineering perspective, but the parameters of the combined lifting system are designed only based on experience. In actual large-scale applications, ineffective situations often occur, resulting in low lifting efficiency of the system. Summary of the invention

[0005] The present application provides a method, device, equipment and storage medium for obtaining parameters of a lifting system, so as to solve the problem that the prior art designs the parameters of a combined lifting system only based on experience, resulting in frequent invalid situations and low lifting efficiency of the system.

[0006] In a first aspect, the present application provides a method for obtaining parameters of a lifting system, wherein the lifting system includes a gas lift valve and an electric submersible pump, the oil pipe is located inside the casing, and the lifting system is installed on the oil pipe, and the method includes:

[0007] Obtaining a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between the tubing pressure and the pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between the casing pressure and the pump hanging depth;

[0008] Determining candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship;

[0009] determining a first inlet pressure of the electric submersible pump according to the selected parameters of the gas lift valve;

[0010] If the difference between the first inlet pressure and the second inlet pressure is within the error range, the candidate parameter of the gas lift valve is used as the target parameter;

[0011] The second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve.

[0012] Optionally, determining candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship specifically includes:

[0013] Determining the depth of the gas injection point according to the first mapping relationship and the second mapping relationship;

[0014] According to the depth of the gas injection point, determine the tubing pressure and annulus pressure at the gas injection point;

[0015] Determine the alternative parameters of the gas lift valve based on the tubing pressure at the gas injection point and the annulus pressure at the gas injection point.

[0016] Optionally, determining the depth of the gas injection point according to the first mapping relationship and the second mapping relationship specifically includes:

[0017] Obtaining the inlet and outlet pressure difference of the electric submersible pump, and determining the intersection point of the first relationship curve and the second relationship curve;

[0018] Determine the depth of the gas injection point according to the intersection of the first relationship curve and the second relationship curve and the inlet and outlet pressure difference of the electric submersible pump;

[0019] The first mapping relationship includes a first relationship curve, and the second mapping relationship includes a second relationship curve.

[0020] Optionally, obtaining the first mapping relationship specifically includes:

[0021] Obtain the tubing pressure at the wellhead and the pump hanging depth of the electric submersible pump;

[0022] According to the tubing pressure at the wellhead and the pump hanging depth of the electric submersible pump, the tubing pressure at multiple depths between the wellhead position and the position where the electric submersible pump is located is determined;

[0023] A first mapping relationship is determined according to the tubing pressures at a plurality of depths.

[0024] Optionally, obtaining a second relationship curve includes:

[0025] The casing pressure at the wellhead is determined according to the preset submergence and the second inlet pressure. The preset submergence is the difference between the electric submersible pump and the dynamic liquid level. The dynamic liquid level is the liquid level in the annular space between the tubing and the casing when the oil well is in normal production.

[0026] According to the casing pressure at the wellhead and the pump hanging depth of the electric submersible pump, the casing pressure at multiple depths between the wellhead position and the position where the electric submersible pump is located is determined;

[0027] A second mapping relationship is determined according to the casing pressures at multiple depths.

[0028] Optionally, the method further comprises:

[0029] If the difference between the first inlet pressure and the second inlet pressure is not within the error range, the casing pressure at the wellhead is updated according to the preset submergence and the first inlet pressure;

[0030] updating the second mapping relationship according to the updated casing pressure at the wellhead and the pump hanging depth of the electric submersible pump;

[0031] updating the candidate parameters of the gas lift valve according to the updated second mapping relationship and the first mapping relationship;

[0032] The first inlet pressure is updated according to the updated optional parameters of the gas lift valve.

[0033] Optionally, before acquiring the first mapping relationship and the second mapping relationship, the method further includes:

[0034] Obtaining basic parameters of the oil well, including the oil well production pressure difference and the oil well productivity;

[0035] Determine the oil well production according to the oil well production pressure difference and oil well productivity;

[0036] Determine the parameters of the electric submersible pump based on the oil well production.

[0037] In a second aspect, the present application provides a parameter acquisition device for a lifting system, the lifting system comprising a gas lift valve and an electric submersible pump, the oil pipe is located inside the casing, the lifting system is installed on the oil pipe, and the device comprises:

[0038] An acquisition module is used to acquire a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is a relationship between tubing pressure and pump hanging depth, the pump hanging depth refers to a depth from a wellhead position to a position where an electric submersible pump is located, and the second mapping relationship is a relationship between casing pressure and pump hanging depth;

[0039] A processing module, configured to determine candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship;

[0040] The processing module is further used to determine a first inlet pressure of the electric submersible pump according to the candidate parameters of the gas lift valve;

[0041] The processing module is further configured to use the candidate parameter of the gas lift valve as the target parameter if the difference between the first inlet pressure and the second inlet pressure is within an error range;

[0042] The second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve.

[0043] In a third aspect, the present application provides an electronic device, including: a memory, a processor;

[0044] Memory; Memory for storing processor executable instructions;

[0045] A processor is used to implement the parameter acquisition method of the lifting system involved in the first aspect and the optional scheme according to the executable instructions stored in the memory.

[0046] In a fourth aspect, the present application provides a computer-readable storage medium, in which computer execution instructions are stored. When the computer execution instructions are executed by a processor, they are used to implement the parameter acquisition method of the lifting system involved in the first aspect and the optional scheme.

[0047] In a fifth aspect, the present application provides a computer program product, including a computer program, which, when executed by a processor, implements the parameter acquisition method of the lifting system involved in the first aspect and the optional scheme.

[0048] The present application provides a method, device, equipment and storage medium for obtaining parameters of a lifting system, which obtain a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between the tubing pressure and the pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between the casing pressure and the pump hanging depth. According to the first mapping relationship and the second mapping relationship, the alternative parameters of the gas lift valve are determined. According to the alternative parameters of the gas lift valve, the first inlet pressure of the electric submersible pump is determined. If the difference between the first inlet pressure and the second inlet pressure is within the error range, the alternative parameters of the gas lift valve are used as the target parameters. Among them, the second inlet pressure is the inlet pressure of the electric submersible pump when there is no gas lift valve. From an engineering perspective, the parameters of the combined lifting system are optimized and designed to improve the stability of the system and the lifting efficiency of the system. BRIEF DESCRIPTION OF THE DRAWINGS

[0049] Figure 1 This is a schematic diagram of an application scenario of a lifting system according to an exemplary embodiment of the present application;

[0050] Figure 2 This is a flow chart of a method for obtaining parameters of a lifting system according to an exemplary embodiment of the present application;

[0051] Figure 3 This is a flow chart of a method for acquiring parameters of a lifting system according to another exemplary embodiment of the present application;

[0052] Figure 4 The characteristic curve of the electric submersible pump is displayed using PIPESIM software;

[0053] Figure 5 A comparison chart showing the mapping relationship between the wellbore flowing pressure and the oil well depth for the original design of the LNA well and this solution;

[0054] Figure 6 This is a schematic structural diagram of a parameter acquisition device for a lifting system according to an exemplary embodiment of the present application;

[0055] Figure 7 It is a schematic diagram of the hardware structure of an electronic device according to an exemplary embodiment of the present application. DETAILED DESCRIPTION

[0056] In order to make the purpose, technical solutions and advantages of this application clearer, the technical solutions in this application will be clearly and completely described below in conjunction with the drawings in this application. Obviously, the described embodiments are part of the embodiments of this application, not all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0057] The technical solution of the present application is described in detail with specific embodiments below. The following specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described in detail in some embodiments.

[0058] In recent years, a large amount of natural gas coexisting with crude oil exists in the oil and gas fields that have been put into development in the Tarim Oilfield. These natural gases are produced from both the combined production of oil and gas layers and the condensate gas layers, as well as the effective gas after gas injection in black oil reservoirs. In view of the lifting problem of such high gas-liquid ratio oil wells, electric submersible pump oil production and gas lift oil production have gradually revealed their own shortcomings. Electric submersible pump oil production has the remarkable characteristic of strong liquid lifting ability. When applied to oil wells suitable for electric submersible pump production, it can meet the production requirements of large oil (liquid) production to the greatest extent. This feature of electric submersible pump oil production technology further strengthens the wide application of this technology in the development and production of offshore oil with few wells, high production capacity and high output. However, at the same time, the application of electric submersible pump oil production technology in offshore oil production also has its limiting factors. The influencing factors often involved are production operation environment, poor working conditions, short trouble-free operation time, frequent pump inspection operations, and long well shut-in waiting time and well repair operation time, which seriously affect the production timeliness, output and economic benefits of oil wells. When there is a convenient and sufficient high-pressure gas source, gas lift oil production is the most economical and easy-to-operate and manage artificial lift oil production method. It has good adaptability to oil well production in different well conditions and can meet the production needs of oil wells in a large production range. The limitation of gas lift oil production technology application is that the maximum capacity of gas lift oil production is limited and cannot meet the production needs of large-volume oil wells. When multiple wells are used, a large-capacity oil and gas separator is required. If used for offshore oil production and development, it will increase the investment and operating costs of offshore production platforms.

[0059] The existing gas lift and ESP combined lifting system selects different lifting modes such as self-flowing, gas lift, electric pump lift, and electric pump and gas lift coupling lift according to the changes in reservoir energy during the oil well production stage through coupling analysis or mathematical modeling, so as to avoid and overcome the technical defects of gas lift and ESP oil production, and give full play to their respective technical advantages. For example, Yang Zhi et al. proposed the design principles and working principles of gas lift-ESP combined lifting, and gave corresponding design processes for four different gas lift-ESP lifting string structures. AITKEN KJ et al. and Cheng Xinping et al. proposed the string structure of gas lift-ESP combined lifting using the self-produced gas of the well, and gave the design process.

[0060] However, the above-mentioned gas lift and electric submersible pump combined lifting system is not designed from an engineering perspective, but the parameters of the combined lifting system are designed only based on experience. In actual large-scale applications, ineffective situations often occur, resulting in low lifting efficiency of the system.

[0061] Table 1 shows the basic data of the 12-well lifting practice implemented by the existing gas lift and electric submersible pump combination lifting system in the Tarim Oilfield. It can be seen from Table 1 that in the 12-well lifting practice, 4 wells were effective and the success rate was only 33.33%. Among the invalid wells, 3 wells were due to the mismatch between the gas lift system and the electric submersible pump system, and the remaining 4 wells were due to low casing pressure. The design of the gas lift valve in the existing gas lift and electric submersible pump combination lifting system is relatively simple: the number of stages changed from 2 in the early stage of application to 1 in the later stage; the gas lift valve is kept at a constant depth of about 300m or 500m; the test bench opening pressure is also almost a fixed value. Therefore, how to optimize the parameter design of the gas lift and electric submersible pump combination lifting system from an engineering perspective is an urgent problem to be solved.

[0062] Table 1

[0063]

[0064] In response to the above problems, the present application proposes a method for obtaining parameters of a lifting system. According to the basic parameters of the oil well, the oil well production is determined. The submersible pump is designed according to the oil well production. After the submersible pump selection and design is completed, the alternative parameters of the gas lift valve are determined according to the inlet pressure of the submersible pump without a gas lift valve, that is, the second inlet pressure. According to the alternative parameters of the gas lift valve, the inlet pressure of the submersible pump with a gas lift valve, that is, the first inlet pressure, is determined. The first inlet pressure is subtracted from the second inlet pressure to obtain the difference. If the difference is within the error range, the alternative parameters of the gas lift valve are used as the target parameters, and the gas lift and submersible pump combined lifting system is obtained according to the target parameters. From an engineering perspective, the parameters of the combined lifting system are optimized to improve the stability of the system and the lifting efficiency of the system.

[0065] Figure 1FIG. 1 is a schematic diagram of an application scenario of a lifting system according to an exemplary embodiment of the present application. Figure 1 As shown, the lifting system provided in this embodiment includes: a gas lift valve 100 and an electric submersible pump 200. The oil pipe 300 is located inside the casing 400, and the lifting system is installed on the oil pipe 300. In order to give full play to the respective advantages of the electric submersible pump and gas lift oil production and overcome their shortcomings, a "Y" type pipe string structure is adopted in which the gas lift oil production pipe string is on the top and the electric submersible pump oil production pipe string is on the bottom without affecting the normal production of the electric submersible pump. Therefore, the maximum lowering depth of the gas lift valve 100 will be limited, and it must be lowered to above the position of the electric submersible pump 200 in the well. When the electric submersible pump needs to be overhauled and wait for operation, the high-pressure gas source on the same platform is used to gas lift the oil well, and the oil well production is maintained by gas lift oil production. The purpose of lifting liquid is achieved by injecting gas to reduce the liquid pressure gradient in the oil pipe above the gas injection point and increase the production pressure difference.

[0066] Figure 2 FIG. 1 is a flow chart of a method for obtaining parameters of a lifting system according to an exemplary embodiment of the present application. Figure 2 As shown, the parameter acquisition method of the lifting system provided in this embodiment is based on Figure 1 The lifting system shown in the figure, the parameter acquisition method of the lifting system comprises the following steps:

[0067] S101. Obtain a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between tubing pressure and pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between casing pressure and pump hanging depth.

[0068] More specifically, the steps of obtaining the first mapping relationship and the second mapping relationship are performed after the design of the electric submersible pump is completed. According to the design of the electric submersible pump, the inlet pressure of the electric submersible pump without a gas lift valve is determined. The first mapping relationship is a mapping relationship between tubing pressure and depth. According to the tubing pressure at the wellhead and the pump hanging depth of the electric submersible pump, the tubing pressure at multiple depths between the wellhead position and the location of the electric submersible pump is determined to obtain the first mapping relationship. Among them, the depth of the wellhead position is 0, and the location of the electric submersible pump is generally 2km to 3km. The second mapping relationship is a mapping relationship between casing pressure and depth. According to the parameters of the electric submersible pump, the second inlet pressure of the electric submersible pump is determined. The second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve. According to the second inlet pressure, the preset submergence and the pump hanging depth, the casing pressure at multiple depths between the wellhead position and the location of the electric submersible pump is determined to obtain the second mapping relationship.

[0069] S102: Determine candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship.

[0070] More specifically, the candidate parameters of the gas lift valve include the number of gas lift valve stages, the depth of the gas lift valve, the aperture of the gas lift valve, the opening pressure of the test bench, the opening pressure on the ground, and the closing pressure on the ground. A coordinate system is established with pressure as the horizontal coordinate and depth as the vertical coordinate, and a first relationship curve and a second relationship curve are drawn according to the first mapping relationship and the second mapping relationship. The first relationship curve represents the mapping relationship between tubing pressure and depth. The second relationship curve represents the mapping relationship between casing pressure and depth. There is a large amount of oil and water in the tubing and a large amount of gas in the casing. The density of oil and water is much greater than the density of gas. Therefore, the slope of the second relationship curve is much greater than the first relationship curve. There must be an intersection between the first relationship curve and the second relationship curve. The depth at the intersection is obtained. Considering the pressure difference when the gas passes through the gas lift valve, the depth at the intersection cannot be directly used as the depth of the gas injection point. Instead, the depth at the intersection is adjusted toward the wellhead by a distance according to the pressure difference when the gas passes through the gas lift valve, and the adjusted depth is used as the depth of the gas injection point. For example, if the pressure difference of gas passing through the gas lift valve is 0.1MPa, the depth of the intersection point is adjusted about 10.2m toward the wellhead to obtain the depth of the gas injection point. According to the depth of the gas injection point, determine the tubing pressure P at the gas injection point. ti and the annular pressure P at the gas injection point ci The oil pipe pressure P at the gas injection point ti Determined according to the first relationship curve. The annular pressure P at the gas injection point ci Determined according to the second relationship curve. Since the density of the gas in the casing is 1.29kg / m 3 , it can be considered that the annular pressure P at the gas injection point ci The casing pressure at the gas injection point is approximately equal to the casing pressure at the gas injection point. ti and the annular pressure P at the gas injection point ci , determine the alternative parameters of the gas lift valve.

[0071] S103: Determine a first inlet pressure of the electric submersible pump according to the alternative parameters of the gas lift valve.

[0072] More specifically, the first inlet pressure of the ESP is the inlet pressure of the ESP with the gas lift valve. According to the test bench opening pressure, the surface opening pressure and the surface closing pressure, the inlet pressure of the ESP with the gas lift valve is calculated, that is, the inlet pressure of the ESP in the gas lift and ESP combined lifting system.

[0073] S104: If the difference between the first inlet pressure and the second inlet pressure is within the error range, the candidate parameters of the gas lift valve are used as target parameters, wherein the second inlet pressure is the inlet pressure of the electric submersible pump without the gas lift valve.

[0074] More specifically, the error range is [-0.35, 0.35], in MPa. The first inlet pressure is subtracted from the second inlet pressure to obtain the difference between the two. If the difference is within the error range, the alternative parameters of the gas lift valve are used as the target parameters. According to the target parameters, the gas lift and electric submersible pump combined lifting system is determined to complete the design of the lifting system.

[0075] In the method provided in this embodiment, a first mapping relationship and a second mapping relationship are obtained, wherein the first mapping relationship is the relationship between the tubing pressure and the pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between the casing pressure and the pump hanging depth. According to the first mapping relationship and the second mapping relationship, the alternative parameters of the gas lift valve are determined. According to the alternative parameters of the gas lift valve, the first inlet pressure of the electric submersible pump is determined. If the difference between the first inlet pressure and the second inlet pressure is within the error range, the alternative parameters of the gas lift valve are used as the target parameters. Among them, the second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve. From an engineering perspective, the parameters of the combined lifting system are optimized and designed to improve the stability of the system and the lifting efficiency of the system.

[0076] Figure 3 FIG. 1 is a flow chart of a method for obtaining parameters of a lifting system according to another exemplary embodiment of the present application. Figure 3 As shown, the method for obtaining parameters of the lifting system provided in this embodiment includes the following steps:

[0077] S201. Obtaining basic parameters of the oil well, including the oil well production pressure difference and the oil well productivity; determining the oil well production according to the oil well production pressure difference and the oil well productivity; and determining parameters of the electric submersible pump according to the oil well production.

[0078] More specifically, to complete the design of the ESP, the process of obtaining the parameters of the ESP is as follows:

[0079] Step 1: Obtain the basic parameters of the oil well. The basic parameters of the oil well include the wellbore structure, the properties of oil, gas and water, the oil well production capacity, the tubing pressure at the wellhead, the oil well production pressure difference, the pump hanging depth, the designed liquid production and the preset submergence, etc., to provide the basic original data required for the design of the following steps.

[0080] Step 2: According to the requirements of the downhole gas separator for the inlet pump gas content in the actual production process, the corresponding pump inlet pressure is found from the inlet pump gas content Fgl table, expressed as Ps. The inlet pump gas content Fgl table includes multiple submersible pumps, the inlet pump gas content of each submersible pump, and the pump inlet pressure of each submersible pump.

[0081] Step 3: Calculate the flow pressure in the middle of the reservoir using the single-phase flow method based on the pump inlet pressure.

[0082] Step 4: According to the flow pressure in the middle of the oil layer, the corresponding oil well production is found from the oil well inflow performance relationship (IPR) table. The IPR table is determined by data such as reservoir production capacity.

[0083] Step 5: Calculate the discharge pressure of the pump using the single-phase liquid flow method according to the oil well production, the tubing pressure at the wellhead, and the pump hanging depth, expressed as Pd, wherein the oil well production is determined based on the oil well production pressure difference and the oil well productivity, and the tubing pressure at the wellhead and the pump hanging depth are obtained based on the prior art.

[0084] Step 6: Determine the total dynamic head of the oil well according to the pump inlet pressure and the pump discharge pressure, expressed as H, in meters. H = 100*(Pd-Ps) / rL, where rL is the specific gravity of the mixed liquid.

[0085] Step 7: Determine the parameters of the electric submersible pump according to the total dynamic head of the oil well and the electric submersible pump characteristic curve, the parameters of the electric submersible pump including the number of stages, displacement and head of the electric submersible pump. The electric submersible pump characteristic curve is obtained according to the prior art.

[0086] S202, obtaining the tubing pressure at the wellhead and the pump depth of the electric submersible pump; determining the tubing pressure at multiple depths from the wellhead position to the position of the electric submersible pump according to the tubing pressure at the wellhead and the pump depth of the electric submersible pump; determining a first mapping relationship according to the tubing pressures at the multiple depths.

[0087] S203. Determine the casing pressure at the wellhead according to a preset submergence and a second inlet pressure, wherein the preset submergence is the difference between the electric submersible pump and the dynamic liquid level, and the dynamic liquid level is the liquid level in the annular space between the tubing and the casing when the oil well is in normal production; determine the casing pressures at multiple depths from the wellhead position to the position of the electric submersible pump according to the casing pressure at the wellhead and the pump hanging depth of the electric submersible pump; determine a second mapping relationship according to the casing pressures at multiple depths.

[0088] S204: Determine the depth of the gas injection point according to the first mapping relationship and the second mapping relationship.

[0089] Optionally, the depth of the gas injection point is determined according to the first mapping relationship and the second mapping relationship, specifically including: obtaining the inlet and outlet pressure difference of the submersible pump, and determining the intersection of the first relationship curve and the second relationship curve; determining the depth of the gas injection point according to the intersection of the first relationship curve and the second relationship curve and the inlet and outlet pressure difference of the submersible pump; wherein the first mapping relationship includes the first relationship curve, and the second mapping relationship includes the second relationship curve.

[0090] More specifically, a coordinate system is established with pressure as the horizontal coordinate and depth as the vertical coordinate, and a first relationship curve and a second relationship curve are drawn according to the first mapping relationship and the second mapping relationship. The first relationship curve represents the mapping relationship between tubing pressure and depth. The second relationship curve represents the mapping relationship between casing pressure and depth. There is an intersection between the first relationship curve and the second relationship curve. The depth at the intersection is obtained. Considering the pressure difference when the gas passes through the gas lift valve, the depth at the intersection cannot be directly used as the depth of the gas injection point. Instead, the depth at the intersection is adjusted toward the wellhead by a certain distance according to the pressure difference when the gas passes through the gas lift valve, and the adjusted depth is used as the depth of the gas injection point. For example, if the pressure difference when the gas passes through the gas lift valve is 0.1 MPa, the depth at the intersection is adjusted toward the wellhead by about 10.2 m to obtain the depth of the gas injection point.

[0091] S205. Determine the tubing pressure and the annulus pressure at the gas injection point according to the depth of the gas injection point.

[0092] More specifically, the tubing pressure P at the injection point is determined according to the depth of the injection point. ti and the annular pressure P at the gas injection point ci The oil pipe pressure P at the gas injection point ti Determined according to the first relationship curve. The annular pressure P at the gas injection point ci Determined according to the second relationship curve. Since the density of the gas in the casing is 1.29kg / m 3 , it can be considered that the annular pressure P at the gas injection point ci The casing pressure at the gas injection point is approximately equal.

[0093] S206. Determine the candidate parameters of the gas lift valve according to the tubing pressure at the gas injection point and the annulus pressure at the gas injection point.

[0094] More specifically, the oil pipe pressure P at the gas injection point ti and the annular pressure P at the gas injection point ci , determine the alternative parameters of the gas lift valve.

[0095] S207. Determine a first inlet pressure of the electric submersible pump according to the alternative parameters of the gas lift valve.

[0096] Among them, step S207 and Figure 2 The implementation of step S103 in the embodiment is similar and will not be described in detail in this embodiment.

[0097] S208: Determine whether the difference between the first inlet pressure and the second inlet pressure is within an error range.

[0098] More specifically, the error range is [-0.35, 0.35], in MPa. If the difference is not within the error range, it means that the spare parameters of the gas lift valve obtained this time cannot make the gas lift and electric submersible pump combined lifting system operate stably, and then go to step S209. If the difference is within the error range, it means that the spare parameters of the gas lift valve obtained this time can make the gas lift and electric submersible pump combined lifting system operate stably, and then go to step S210.

[0099] S209. If the difference between the first inlet pressure and the second inlet pressure is not within the error range, the casing pressure of the wellhead is updated according to the preset submergence degree and the first inlet pressure; the second mapping relationship is updated according to the updated casing pressure of the wellhead and the pump hanging depth of the electric submersible pump; the alternative parameters of the gas lift valve are updated according to the updated second mapping relationship and the first mapping relationship; the first inlet pressure is updated according to the updated alternative parameters of the gas lift valve.

[0100] More specifically, if the difference between the first inlet pressure and the second inlet pressure is not within the error range, the casing pressure of the wellhead is updated according to the preset silence and the first inlet pressure; the casing pressure at multiple depths between the wellhead position and the position of the electric submersible pump is updated according to the updated casing pressure at the wellhead and the pump hanging depth of the electric submersible pump. According to the updated casing pressures at multiple depths, the second mapping relationship is updated, that is, the second relationship curve is updated. According to the first relationship curve and the updated second relationship curve, the depth of the gas injection point is updated. According to the updated depth of the gas injection point, the tubing pressure of the gas injection point and the annulus pressure of the gas injection point are updated. According to the updated tubing pressure of the gas injection point and the updated annulus pressure of the gas injection point, the alternative parameters of the gas lift valve are updated. According to the updated alternative parameters of the gas lift valve, the first inlet pressure is updated. Enter step S08 to determine whether the difference between the updated first inlet pressure and the second inlet pressure is within the error range, wherein the second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve.

[0101] S210: If the difference between the first inlet pressure and the second inlet pressure is within an error range, the candidate parameters of the gas lift valve are used as target parameters.

[0102] Among them, step S210 and Figure 2 The implementation of step S104 in the embodiment is similar and will not be described in detail in this embodiment.

[0103] In the method provided in this embodiment, the two subsystems of the electric submersible pump and the gas lift are organically integrated to design a combined lifting system of the gas lift and the electric submersible pump, and the parameters of the lifting system are optimized to ensure stable operation of the lifting system and improve the efficiency of the lifting system.

[0104] It is worth noting that there is still a lack of field design software in the design of lifting systems. This application relies on the mainstream commercial software PIPESIM, uses EXCEL VBA technology, integrates the two subsystems of gas lift and electric submersible pump, writes a set of software, and performs parameter design of self-produced gas lift and electric submersible pump combined lifting system for multiple wells, proving its operational stability and applicability to the field.

[0105] Figure 4 The characteristic curve of the electric submersible pump is displayed using PIPESIM software. Figure 4 As shown in the figure, according to the total dynamic head of the oil well and the characteristic curve of the electric submersible pump, the parameters of the electric submersible pump are determined. The parameters of the electric submersible pump include the number of stages, displacement and head of the electric submersible pump. According to the parameters of the electric submersible pump, the electric submersible pump model is established to complete the design of the electric submersible pump.

[0106] Figure 5 This is a comparison chart of the mapping relationship between the wellbore flow pressure and the oil well depth of the original design of the LNA well and this solution. Figure 5 As shown in the figure, the horizontal axis is the wellbore flow pressure, and the vertical axis is the oil well depth. The original design standard state of liquid production is 188.0859m 3 / day. This solution optimizes the parameters of the lifting system, and the liquid production under standard conditions is 196.0813m 3 / day. Compared with the original design, the method provided in this application increases the liquid production.

[0107] Table 2 is a comparison table of the lifting system parameter design of the original design of the LNA well and the present solution. As can be seen from Table 2, in the lifting system of the original design, the number of gas lift valve stages is 2. The gas lift valve depth is constant at about 300m or 500m. The method provided in this application optimizes the lifting system parameters from the aspects of electric submersible pump displacement and head, gas lift valve stage, gas lift valve depth, gas lift valve aperture, test bench opening pressure and ground opening pressure.

[0108] Table 2

[0109]

[0110] Figure 6 FIG. 1 is a schematic diagram of a parameter acquisition device for a lifting system according to an exemplary embodiment of the present application. Figure 6 As shown, the present application provides a parameter acquisition device 40 for a lifting system, the lifting system includes a gas lift valve and an electric submersible pump, the oil pipe is located inside the casing, the lifting system is installed on the oil pipe, and the device 40 includes:

[0111] The acquisition module 41 is used to obtain a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between the tubing pressure and the pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between the casing pressure and the pump hanging depth.

[0112] The processing module 42 is used to determine candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship.

[0113] The processing module 42 is further configured to determine a first inlet pressure of the electric submersible pump according to the candidate parameters of the gas lift valve.

[0114] The processing module 42 is further configured to use the candidate parameters of the gas lift valve as target parameters if the difference between the first inlet pressure and the second inlet pressure is within an error range.

[0115] The second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve.

[0116] Specifically, this embodiment can refer to the above method embodiment, and its principles and technical effects are similar and will not be repeated here.

[0117] Figure 7 FIG. 1 is a schematic diagram of the hardware structure of an electronic device according to an exemplary embodiment of the present application. Figure 7 As shown, the electronic device 50 of this embodiment includes: a processor 51 and a memory 52; wherein,

[0118] The memory 52 is a memory for storing processor executable instructions.

[0119] The processor 51 is used to implement the parameter acquisition method of the lifting system in the above embodiment according to the executable instructions stored in the memory. For details, please refer to the relevant description in the above method embodiment.

[0120] Optionally, the memory 52 may be independent or integrated with the processor 51 .

[0121] When the memory 52 is independently provided, the electronic device 50 further includes a bus 53 for connecting the memory 52 and the processor 51 .

[0122] The present application also provides a computer-readable storage medium, in which computer instructions are stored. When the computer instructions are executed by a processor, they are used to implement the methods provided in the various embodiments described above.

[0123] Among them, the computer-readable storage medium can be a computer storage medium or a communication medium. The communication medium includes any medium that facilitates the transmission of a computer program from one place to another. The computer storage medium can be any available medium that can be accessed by a general-purpose or special-purpose computer. For example, a computer-readable storage medium is coupled to a processor so that the processor can read information from the computer-readable storage medium and write information to the computer-readable storage medium. Of course, the computer-readable storage medium can also be a component of the processor. The processor and the computer-readable storage medium can be located in an application-specific integrated circuit (ASIC). In addition, the ASIC can be located in a user device. Of course, the processor and the computer-readable storage medium can also exist in a communication device as discrete components.

[0124] The computer-readable storage medium may be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk or optical disk. The storage medium may be any available medium that can be accessed by a general or special-purpose computer.

[0125] The present application also provides a computer program product, which includes an execution instruction, which is stored in a computer-readable storage medium. At least one processor of the device can read the execution instruction from the computer-readable storage medium, and at least one processor executes the execution instruction so that the device implements the methods provided in the various embodiments described above.

[0126] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit it. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for obtaining parameters of a lifting system, characterized in that: The lifting system includes a gas lift valve and an electric submersible pump, the oil pipe is located inside the casing, the lifting system is installed on the oil pipe, and the method includes: Acquire a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is the relationship between tubing pressure and pump hanging depth, the pump hanging depth refers to the depth from the wellhead position to the position of the electric submersible pump, and the second mapping relationship is the relationship between casing pressure and pump hanging depth; Determining candidate parameters of a gas lift valve according to the first mapping relationship and the second mapping relationship; determining a first inlet pressure of the electric submersible pump according to the alternative parameters of the gas lift valve; If the difference between the first inlet pressure and the second inlet pressure is within an error range, taking the candidate parameter of the gas lift valve as a target parameter; Wherein, the second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve; The obtaining of the second mapping relationship includes: Determining the casing pressure at the wellhead according to a preset submergence and the second inlet pressure, wherein the preset submergence is the difference between the electric submersible pump and a dynamic liquid level, and the dynamic liquid level is the liquid level in the annular space between the tubing and the casing when the oil well is in normal production; Determine the casing pressure at multiple depths between the wellhead and the location of the electric submersible pump according to the casing pressure at the wellhead and the pump hanging depth of the electric submersible pump; The second mapping relationship is determined according to the casing pressures at the multiple depths.

2. The method according to claim 1, characterized in that: The determining the candidate parameters of the gas lift valve according to the first mapping relationship and the second mapping relationship specifically includes: Determining the depth of the gas injection point according to the first mapping relationship and the second mapping relationship; According to the depth of the gas injection point, determining the tubing pressure at the gas injection point and the annulus pressure at the gas injection point; The candidate parameters of the gas lift valve are determined according to the tubing pressure at the gas injection point and the annulus pressure at the gas injection point.

3. The method according to claim 2, characterized in that The determining the depth of the gas injection point according to the first mapping relationship and the second mapping relationship specifically includes: Obtaining the inlet and outlet pressure difference of the electric submersible pump, and determining the intersection point of the first relationship curve and the second relationship curve; Determining the depth of the gas injection point according to the intersection of the first relationship curve and the second relationship curve and the inlet and outlet pressure difference of the electric submersible pump; The first mapping relationship includes the first relationship curve, and the second mapping relationship includes the second relationship curve.

4. The method according to claim 1, characterized in that: The obtaining of the first mapping relationship specifically includes: Obtaining the tubing pressure at the wellhead and the pump hanging depth of the electric submersible pump; Determine the tubing pressure at multiple depths between the wellhead and the location of the electric submersible pump according to the tubing pressure at the wellhead and the pump hanging depth of the electric submersible pump; The first mapping relationship is determined according to the oil pipe pressures at the multiple depths.

5. The method according to claim 1, characterized in that: The method further comprises: If the difference between the first inlet pressure and the second inlet pressure is not within the error range, updating the casing pressure at the wellhead according to the preset submergence degree and the first inlet pressure; updating the second mapping relationship according to the updated casing pressure at the wellhead and the pump hanging depth of the electric submersible pump; updating the candidate parameters of the gas lift valve according to the updated second mapping relationship and the first mapping relationship; The first inlet pressure is updated according to the updated optional parameters of the gas lift valve.

6. The method according to any one of claims 1 to 5, characterized in that Before acquiring the first mapping relationship and the second mapping relationship, the method further includes: Obtaining basic parameters of the oil well, wherein the basic parameters of the oil well include production pressure difference and oil well productivity; Determining the oil well production according to the oil well production pressure difference and the oil well production capacity; The parameters of the electric submersible pump are determined according to the oil well production.

7. A parameter acquisition device for a lifting system, characterized in that: The lifting system includes a gas lift valve and an electric submersible pump. The oil pipe is located inside the casing. The lifting system is installed on the oil pipe. The device includes: An acquisition module, configured to acquire a first mapping relationship and a second mapping relationship, wherein the first mapping relationship is a relationship between tubing pressure and pump hanging depth, the pump hanging depth being a depth from a wellhead position to a position where the electric submersible pump is located, and the second mapping relationship is a relationship between casing pressure and pump hanging depth; A processing module, configured to determine candidate parameters of a gas lift valve according to the first mapping relationship and the second mapping relationship; The processing module is further used to determine a first inlet pressure of the electric submersible pump according to the alternative parameters of the gas lift valve; The processing module is further configured to use the candidate parameter of the gas lift valve as a target parameter if the difference between the first inlet pressure and the second inlet pressure is within an error range; Wherein, the second inlet pressure is the inlet pressure of the electric submersible pump without a gas lift valve; The acquisition module is specifically used for: Determining the casing pressure at the wellhead according to a preset submergence and the second inlet pressure, wherein the preset submergence is the difference between the electric submersible pump and a dynamic liquid level, and the dynamic liquid level is the liquid level in the annular space between the tubing and the casing when the oil well is in normal production; Determine the casing pressure at multiple depths between the wellhead and the location of the electric submersible pump according to the casing pressure at the wellhead and the pump hanging depth of the electric submersible pump; The second mapping relationship is determined according to the casing pressures at the multiple depths.

8. An electronic device, characterized in that: include: Memory, processor; Memory; a memory for storing instructions executable by the processor; A processor, configured to implement the parameter acquisition method of the lifting system according to any one of claims 1 to 6 according to the executable instructions stored in the memory.

9. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the parameter acquisition method for the lifting system according to any one of claims 1 to 6.

10. A computer program product, comprising a computer program, characterized in that When the computer program is executed by a processor, the method for obtaining parameters of the lifting system according to any one of claims 1 to 6 is implemented.

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