CN115324885A - Method, device and equipment for determining well selection of electric submersible screw pump and storage medium - Google Patents

Method, device and equipment for determining well selection of electric submersible screw pump and storage medium Download PDF

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Publication number
CN115324885A
CN115324885A CN202110447759.4A CN202110447759A CN115324885A CN 115324885 A CN115324885 A CN 115324885A CN 202110447759 A CN202110447759 A CN 202110447759A CN 115324885 A CN115324885 A CN 115324885A
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China
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data
pump
screw pump
suction inlet
pressure
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张红朋
安九泉
杨建平
邱衍辉
董绍刚
杨志祥
吴超
张朝升
喻波
韩峰
段晓旭
张硕
金姗姗
卢玉
陶硕
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Petrochina Co Ltd
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Petrochina Co Ltd
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
    • F04C2/00—Rotary-piston machines or pumps
    • F04C2/08—Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing
    • F04C2/10—Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member
    • F04C2/107—Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
    • F04C14/00—Control of, monitoring of, or safety arrangements for, machines, pumps or pumping installations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
    • F04C14/00—Control of, monitoring of, or safety arrangements for, machines, pumps or pumping installations
    • F04C14/28—Safety arrangements; Monitoring

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  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Control Of Positive-Displacement Pumps (AREA)

Abstract

The invention relates to the technical field of oil exploitation, in particular to a method, a device, equipment and a storage medium for determining well selection of an electric submersible screw pump, wherein the method comprises the following steps: obtaining data of the screw pump according to the pressure of a pump suction inlet of the screw pump and the predicted yield of the oil well, wherein the pressure of the pump suction inlet is obtained according to natural gas data, crude oil data and water-containing data in the oil well, and the predicted yield is obtained according to historical yield 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-machine data of the control cabinet according to the motor data, the cable data and 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 optimized well selection of the electric submersible screw pump, improves the applicability of the electric submersible screw pump, realizes the oil well production balance, and prolongs the pump inspection period of the oil well.

Description

Method, device and equipment for determining well selection of electric submersible screw pump and storage medium
Technical Field
The invention relates to the technical field of oil exploitation, in particular to a method, a device, equipment and a storage medium for determining well selection of an electric submersible screw pump.
Background
The lifting mode of the sucker-rod pump is influenced by factors such as well trajectory, crude oil physical properties and oil reservoir characteristics, and the eccentric wear of pipes and rods is inevitable. With the gradual deepening of oil field development, phenomena of water content increase, crude oil viscosity increase, eccentric wear aggravation and the like can occur. These phenomena cause the rod pump to have the situations of pump clamping, rod clamping, pump abrasion, sucker rod breaking and the like, and result in frequent and even production stop of oil well operation. For example, the scrappage of sucker-rod pumps in oil fields is gradually increased due to eccentric wear of pipe rods.
In view of the disadvantages of the sucker-rod pump, an electric submersible screw pump is commonly used. The lifting technology of the electric submersible screw pump is a rodless pump lifting technology, and the underground permanent magnet direct drive motor drives the underground screw pump to pump underground crude oil, so that crude oil lifting is realized. Different from a rod pump, the screw pump lifts crude oil by virtue of a sealed cavity formed by the rotor and the stator, and has certain advantages of carrying sand or slurry for oil extraction.
However, in the field application process, the oil property, the crude oil physical property, the liquid supply capacity and other factors influence, relevant standards and regulations are temporarily absent, and the well selection of the electric submersible screw pump is determined. At present, the method is still implemented according to the related design of the original well pumping unit, and the problem of low utilization rate of the electric submersible screw pump well can be caused.
Disclosure of Invention
The embodiment of the application provides a method, a device, equipment and a storage medium for determining well selection of the electric submersible screw pump, solves the technical problem of low utilization rate of the electric submersible screw pump in the prior art, provides a well selection basis of the electric submersible screw pump, improves the applicability of the electric submersible screw pump, realizes oil well production balance, and prolongs the pump detection period of an oil well.
In a first aspect, an embodiment of the present invention provides a method for determining well selection of an electric submersible screw pump, where 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, and the method includes:
obtaining screw pump data from a pump suction pressure of the screw pump and from predicted production of the well, wherein the pump suction pressure is obtained from natural gas data, crude oil data, and water data in the well, and the predicted production is obtained from historical production and historical pressure of the 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;
acquiring cabinet machine data of the control cabinet according to the motor data, the cable data and 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 machine data.
Preferably, the step of obtaining the pressure at the pump inlet includes:
measuring pressure values of a plurality of pump suction inlets through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected with the submersible motor;
obtaining a 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-containing data and each pump suction inlet pressure value, and obtaining a corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio;
according to a target pump suction inlet gas-liquid ratio, searching a pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio to determine the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within a gas-liquid ratio threshold range.
Preferably, the obtaining a gas-liquid ratio of the pump suction inlet corresponding to each pressure value of the pump suction inlet according to the natural gas data, the crude oil data, the water-containing data and each pressure value of the pump suction inlet, and obtaining a corresponding relationship between each pressure value of the pump suction inlet and the corresponding gas-liquid ratio of the pump suction inlet includes:
obtaining a saturated dissolved gas-oil ratio at a saturation pressure according to the natural gas relative density in the natural gas data, the crude oil relative density in the crude oil data, the saturation 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 pressure value of the pump suction inlet and the saturation pressure;
obtaining the volume coefficient of natural gas according to the temperature of the pump hanging position of the screw pump and the pressure value of the pump suction inlet;
obtaining the oil layer crude oil volume coefficient according to the natural gas relative density, the crude oil relative density and the corrected dissolved gas-oil ratio;
obtaining the gas-liquid ratio of the corresponding pump suction inlet according to the production gas-oil ratio, the water content of the water-containing data, the corrected dissolved gas-oil ratio, the volume coefficient of the natural gas, the volume coefficient of the oil-gas-water mixture of the pump suction inlet of the screw pump and the volume coefficient of the crude oil in the oil layer;
and obtaining the corresponding relation according to the pressure value of each suction inlet and the gas-liquid ratio of the corresponding pump suction inlet.
Preferably, the step of obtaining the predicted yield comprises:
obtaining the projected production from a formation pressure of the well, a bottom hole flow pressure of the well, and a well production in the historical production.
Preferably, the obtaining screw pump data from the pump suction pressure of the screw pump and the predicted production of the well comprises:
obtaining the theoretical displacement of the screw pump according to the displacement per revolution of the screw pump and the rotating speed of the screw pump;
obtaining actual output according to the theoretical displacement and the pump efficiency of the screw pump;
if the target actual output is not smaller than the predicted output, determining the theoretical displacement of the screw pump corresponding to the target actual output as the actual displacement of the screw pump;
obtaining a total dynamic pressure head of the screw pump according to the pump hanging depth, the oil pressure conversion pressure head, the oil pipe abrasion resistance loss pressure head and the pump suction inlet pressure conversion pressure head of the screw pump;
and if the target lift is not smaller than the total dynamic pressure head, determining that the target lift is the lift of the screw pump, wherein the target lift is the lifting height of the screw pump, and the screw pump data comprises the lift of the screw pump and the actual discharge capacity of the screw pump.
Preferably, the obtaining of the motor data of the submersible motor according to the screw pump data includes:
obtaining the torque of the submersible motor according to the driving torque under the zero pressure head and the lift of the screw pump;
and obtaining the shaft power of the submersible motor according to the actual discharge capacity of the screw pump, the lift of the screw pump, the average relative density of well fluid of the oil well and the pump efficiency, wherein the motor data comprises the torque of the submersible motor and the shaft power of the submersible motor.
Preferably, the obtaining of the cable data of the submersible cable according to the well temperature and the 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 hanging depth;
obtaining the pressure drop loss and the 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 a model of the submersible cable, a length of the submersible cable, a pressure drop loss and a power loss of the submersible cable.
Based on the same inventive concept, in a second aspect, the invention further provides a device for determining well selection of the electric submersible screw pump, wherein the electric submersible screw pump comprises a screw pump, a submersible motor, a submersible cable and a control cabinet, the control cabinet is connected with the submersible motor through the submersible cable, and the submersible motor is also connected with the screw pump, and the device is characterized by comprising:
the screw pump data module is used for obtaining screw pump data according to the pressure of a pump suction inlet of the screw pump and the predicted yield of the oil well, wherein the pressure of the pump suction inlet is obtained according to natural gas data, crude oil data and water content data in the oil well, and the predicted yield is obtained according to historical yield and historical pressure of the oil well;
the motor data module is used for obtaining motor data of the submersible motor according to the screw pump data;
the cable data module is used for obtaining the cable data of the submersible cable according to the oil well temperature and the motor data;
the cabinet machine data module is used for acquiring cabinet machine data of the control cabinet according to the motor data, the cable data and the wellhead environment data of the oil well;
and the production module is used for determining the 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.
Based on the same inventive concept, in a third aspect, the present invention provides a computer apparatus comprising a memory, a processor and a computer program stored on the memory and executable on the processor, the processor implementing the steps of the method for determining a well selection of an electric submersible progressive cavity pump when executing the program.
Based on the same inventive concept, in a fourth aspect, the invention provides a computer readable storage medium having stored thereon a computer program which, when being executed by a processor, performs the steps of a method of determining a well selection for an electric submersible screw pump.
One or more technical solutions in the embodiments of the present invention have at least the following technical effects or advantages:
in the embodiment of the application, the natural gas data, the crude oil data, the water content data, the historical yield of the oil well, the oil well pressure and other data in the oil well are collected, dynamic analysis is carried out, and the screw pump data, the motor data, the cable data and the cabinet machine data are obtained, so that the appropriate production allocation of the screw pump, the submersible motor, the submersible cable and the control cabinet is determined, the discharge capacity and the lift of the screw pump are optimized, the shaft power of the motor, the cable, the control cabinet and other parameters are determined, the optimal well selection of the electric submersible screw pump is realized, the applicability of the electric submersible screw pump is improved, the oil well production supply balance is realized, and the oil well pump detection period is prolonged.
Drawings
Various additional advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Also, like reference numerals are used to refer to like parts throughout the drawings. In the drawings:
FIG. 1 is a schematic flow chart illustrating steps of a method for determining well selection of an electric submersible screw pump according to an embodiment of the invention;
FIG. 2 shows a schematic structural diagram of an electric submersible screw pump in an embodiment of the invention;
FIG. 3 shows a block schematic diagram of a determination device for electric submersible progressive cavity pump well selection in an embodiment of the present invention;
fig. 4 shows a schematic structural diagram of a computer device in an embodiment of the present invention.
Detailed Description
Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be embodied in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.
Example one
The invention provides a method for determining well selection of an electric submersible screw pump, which is applied to the electric submersible screw pump. In order to clearly describe the method for determining the well selection of the electric submersible screw pump, firstly, the structure of the electric submersible screw pump needs to be described. As shown in fig. 2, the electric submersible screw pump includes: the device comprises a downhole centralizer 201, a temperature and pressure measuring device 202, an oil-submersible motor 203, a motor protector 204, a coupling 205, a screw pump 206, an oil-submersible cable 207, a check valve 208, an oil drain 209, an electric pump wellhead 210, a junction box 211 and a control cabinet 212.
The underground centralizer 201 is arranged at the lowest end of the electric submersible screw pump 206 and is close to an oil layer. The downhole centralizer 201 is used for downhole centralization to eliminate 206 axial force during rotation of the screw pump.
And the temperature and pressure measuring device 202 is arranged above the underground centralizer 201, and the temperature and pressure measuring device 202 is connected with the submersible motor 203. The temperature and pressure measuring device 202 is used for measuring the temperature at the bottom of the well and tracking the temperature rise change of the submersible motor 203 in real time; and the bottom hole pressure is measured, the sinking pressure of the oil well is converted, and the screw pump 206 is prevented from dry pumping.
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, which is concentric rotation. The motor protector 204 is used for providing a motor oil expansion space for the submersible motor 203 when the submersible motor 203 is heated up and cooled down.
The coupling 205 is arranged between the submersible motor 203 and the screw pump 206; and one end of the coupling 205 is connected with the submersible motor 203, and the other end is connected with the screw pump 206. The coupling 205 is used to convert the concentric rotation of the submersible motor 203 into the eccentric rotation of the screw pump 206.
And a screw pump 206 arranged above the coupling 205. The screw pump 206 is used to lift the crude oil to the surface via the screw pump 206.
And the check valve 208 is arranged on the screw pump 206 and is used for preventing the liquid column and crude oil in the liquid column from containing sand to enter the screw pump 206 in the shutdown process.
And the oil drain 209 is arranged above the check valve 208 and is used for realizing environment-friendly operation in the well raising process.
And the control cabinet 212 is arranged on the ground and is connected with the submersible motor 203 through the junction box 211 and the submersible cable 207. The control cabinet 212 is used for ground parameter adjustment and providing electric energy for the electric submersible screw pump. Junction box 211 is positioned at the surface to avoid insulating impact of downhole gases on control cabinet 212. The submersible cable 207 is used to transfer surface electrical power to the submersible motor 203 downhole.
After the structure and the principle of the electric submersible screw pump are known, a method for determining well selection of the electric submersible screw pump is described in detail. As shown in fig. 1, includes:
s101, obtaining screw pump data according to the pump suction inlet pressure of a screw pump 206 and the predicted yield of the oil well, wherein the pump suction inlet pressure is obtained according to natural gas data, crude oil data and water content data in the oil well, and the predicted yield is obtained according to historical yield and historical pressure of the oil well;
s102, obtaining motor data of the submersible motor 203 according to the screw pump data;
s103, obtaining cable data of the submersible cable 207 according to the oil well temperature and the motor data;
s104, obtaining cabinet-machine data of the control cabinet 212 according to the motor data, the cable data and wellhead environment data of the oil well;
and S105, 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.
It should be noted that the method collects relevant data at an earlier stage, such as natural gas data, crude oil data, water content data, historical production of the well, historical pressure of the well, and the like. Historical production is data relating to the liquids that have been produced, including daily production fluids, the volume of crude oil in the daily production fluids, the water content in the daily production crude oil volume, the daily volume of natural gas produced, and the like. The historical pressure includes formation pressure of the well, bottom hole flow pressure of the well, etc.
According to the method, dynamic analysis is carried out through data collection of natural gas data, crude oil data, water content data, historical yield of an oil well, oil well pressure and the like in the oil well, and screw pump data, motor data, cable data and cabinet machine data are obtained, so that proper production allocation of the screw pump 206, the submersible motor 203, the submersible cable 207 and the control cabinet 212 is determined, the discharge capacity and the lift of the screw pump 206 are optimized, axial power of the submersible motor 203, electrical parameters of the cable, the control cabinet 212 and the like are determined, optimal well selection of the electric submersible screw pump is achieved, the applicability of the electric submersible screw pump is improved, oil well production balance is achieved, and the pump inspection period of the oil well is prolonged.
The following describes in detail, with reference to fig. 1, specific implementation steps of the method for determining a well selection of an electric submersible screw pump provided in this embodiment:
first, step S101 is performed to obtain progressing cavity pump data based on a pump inlet pressure of the progressing cavity pump 206, which is obtained based on natural gas data, crude oil data, and water content data in the oil well, and a predicted production of the oil well, which is obtained based on a historical production and a historical pressure of the oil well.
In step S101, the pump inlet pressure of the screw pump 206 and the expected production rate of the well are obtained, and then the screw pump data is obtained according to the pump inlet pressure and the expected production rate. It should be noted that the order of the process of obtaining the pump suction pressure and the process of obtaining the expected production rate may be switched or may be performed simultaneously.
Specifically, the process of obtaining the pump suction pressure: measuring a plurality of pressure values of the pump suction inlet by a temperature and pressure measuring device 202, wherein the temperature and pressure measuring device 202 is connected with the submersible motor 203; obtaining a gas-liquid ratio of a pump suction inlet corresponding to the pressure value of each pump suction inlet according to the natural gas data, the crude oil data, the water-containing data and the pressure value of each pump suction inlet, and obtaining a corresponding relation between the pressure value of each pump suction inlet and the gas-liquid ratio of the corresponding pump suction inlet; and according to the gas-liquid ratio of the target pump suction inlet, finding the pump suction inlet pressure value corresponding to the gas-liquid ratio of the target pump suction inlet from the corresponding relation between each pump suction inlet pressure value and the corresponding gas-liquid ratio of the pump suction inlet, and determining the pump suction inlet pressure value as the gas-liquid ratio of the pump suction inlet, wherein the gas-liquid ratio of the target pump suction inlet is within the gas-liquid ratio threshold range.
Specifically, the temperature and pressure measuring device 202 measures a plurality of pump inlet pressure values. And combining the pressure value of each pump suction inlet with natural gas data, crude oil data and water-containing data to obtain the gas-liquid ratio of the pump suction inlet corresponding to the pressure value of each pump suction inlet. And then, obtaining a corresponding relation according to the pressure value of each pump suction inlet and the corresponding gas-liquid ratio of each pump suction inlet, and drawing a corresponding relation curve. And finally, screening out a target pump suction inlet gas-liquid ratio from the plurality of pump suction inlet gas-liquid ratios, and determining a pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio as the pump suction inlet pressure through the corresponding relation. The gas-liquid ratio of the suction inlet of the target pump is within a gas-liquid ratio threshold range, the gas-liquid ratio threshold range is usually 0-25%, and the gas-liquid ratio threshold range can also be set according to actual requirements.
In the embodiment described herein, when crude oil, natural gas, and water enter the screw pump 206, the volume of natural gas occupying the space in the screw pump 206 will reduce the filling level of the screw pump 206. Therefore, in order to improve the pumping efficiency of the screw pump 206, a reasonable pump inlet gas-liquid ratio is determined, which is significant for the operation of the screw pump 206 under the oil well.
In the embodiment of the present description, the process of calculating the gas-liquid ratio of the pump suction inlet corresponding to each pressure value of the pump suction inlet and the corresponding relationship between each pressure value of the pump suction inlet and the corresponding gas-liquid ratio of the pump suction inlet includes:
in the first step, the saturated dissolved gas-oil ratio under the saturation pressure is obtained 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 an oil well.
Specifically, by the formula (1), the dissolved gas-oil ratio at saturation pressure is obtained;
Figure BDA0003037500070000091
wherein R is sb M is the saturated dissolved gas-oil ratio at saturation pressure 3 /m 3 ；γ g Is the relative density of natural gas; gamma ray 0 Is the relative density of the crude oil; p is a radical of b Is the saturation pressure, MPa; t is the bottom hole temperature in deg.C.
Because the bottom hole flowing pressure is generally lower than the saturation pressure in the oil pumping process of the electric submersible screw pump. Therefore, for the case where the bottom hole stream pressure is lower than the saturation pressure, the calculated dissolved gas-oil ratio must be corrected to compensate for the case where the bottom hole stream pressure is lower than the saturation pressure.
And secondly, after the dissolved gas-oil ratio under the saturation pressure is obtained, correcting 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 pressure value of the suction port of the pump and the saturation pressure.
Specifically, the ratio of the pressure value of the pump suction inlet to the saturation pressure, i.e., the correction coefficient is obtained by formula (2);
Figure BDA0003037500070000101
wherein, f c For the correction factor, p is the pump suction pressure value, MPa.
Obtaining a corrected dissolved gas-oil ratio through a formula (3);
R sp ＝R sb ×f c (3)；
wherein R is sp For corrected dissolved gas-oil ratio, m 3 /m 3 。
And thirdly, obtaining the volume coefficient of the natural gas according to the temperature of the pump hanging position of the screw pump 206 and the pressure value of the pump suction inlet.
Specifically, a natural gas volume coefficient is obtained by formula (4);
Figure BDA0003037500070000102
wherein, B g Is the volume coefficient of natural gas, m 3 /m 3 (ii) a Z is the natural gas compression coefficient, generally between 0.81 and 0.91; t is t b The temperature of the pump hanging position is measured in DEG C.
And fourthly, obtaining the volume coefficient of the crude oil in the oil layer according to the relative density of the natural gas, the relative density of the crude oil and the corrected dissolved gas-oil ratio.
In particular, reservoir crude oil volume factor, refers to the ratio of a unit volume of crude oil to its volume after complete degassing under formation conditions. And (5) obtaining the crude oil volume coefficient of the oil layer.
Figure BDA0003037500070000103
Wherein, B 0 The volume factor of crude oil in oil reservoir.
And fifthly, obtaining a corresponding pump gas-liquid suction inlet volume ratio according to a production gas-oil ratio, the water content of the water-containing data, the corrected dissolved gas-oil ratio, the natural gas volume coefficient, the pump suction inlet oil-gas-water mixture volume and the oil layer crude oil volume coefficient of the screw pump 206, wherein the production gas-oil ratio is the ratio of the natural gas volume to the crude oil volume in the historical yield, and the pump suction inlet oil-gas-water mixture volume is the volume of the mixture of the crude oil, the natural gas and the water at the pump suction inlet of the screw pump 206.
The gas-liquid ratio of the pump suction inlet is obtained by deducing the ratio of the volume of the natural gas of the pump suction inlet to the total volume of the mixture of the natural gas, crude oil and water of the pump suction inlet, and the concrete deduction process is as follows:
Figure BDA0003037500070000111
wherein GLR is the gas-liquid ratio of a pump suction inlet,%; v g Is the volume of natural gas at the suction inlet of the pump, m 3 ；V 0 For the pump suction port crude oil volume, m 3 ；V w Water volume, m, of the pump suction inlet 3 ；V t For pump suction of volume of oil-gas-water mixture, i.e. V t ＝V 0 +V g +V w 。
Due to the fact that
Figure BDA0003037500070000112
Substituting into the formula (6), and simplifying into the formula (7);
Figure BDA0003037500070000113
wherein f is w Water content,%; GOR to produce gas oilRatio,%.
It should be noted that the produced gas to oil ratio GOR is the ratio of the volume of natural gas to the volume of crude oil in the historical production. For example, assume that in historical production, a single well produces 10m of fluid per day 3 The water content is 10 percent, and the volume of the produced natural gas per day is 1000m 3 The crude oil volume produced per day is 9m 3 The produced gas-oil ratio is 9/1000. The production gas oil ratio can be the ratio of the volume average of crude oil produced per day to the volume average of natural gas produced per day, can also be the ratio of the volume average of crude oil produced per day in the last 3 months of the exploration field to the volume average of natural gas produced per day in the last 3 months of the exploration field, and can also be set according to actual requirements.
And sixthly, obtaining a corresponding relation according to the pressure value of each suction inlet and the gas-liquid ratio of the corresponding pump suction inlet.
Specifically, the gas-liquid ratio of the pump suction inlet under different pressure values of the pump suction inlet is calculated, and a corresponding relation curve of the pressure value of the pump suction inlet and the gas-liquid ratio of the pump suction inlet is made. In order to improve the pumping efficiency, a pump inlet pressure value corresponding to a gas-liquid ratio of a pump inlet of less than 25% is generally taken as the pump inlet pressure, so that natural gas separated from crude oil is prevented from entering the pump under certain specific pressure and occupying the space of the screw pump 206.
In the examples of the present specification, the process of obtaining the predicted yield includes: the predicted production is obtained based on the formation pressure of the well, the bottom hole flow pressure of the well, and the well production in the historical production.
Specifically, when the bottom hole pressure of the well is below the saturation pressure, the crude oil starts to degas, and the seepage in the formation is crude oil, natural gas two-phase or crude oil, natural gas, water three-phase seepage, the curve of production versus bottom hole pressure is expected to bend, and they all follow the following relationship:
Figure BDA0003037500070000121
wherein p is R Is the formation pressure, MPa; p is a radical of wf The bottom hole flowing pressure is MPa; q is oilWell production, m 3 /d；q max For the expected yield, also the maximum yield, m 3 /d。
The well production q may be an average value of daily production fluids in the historical production, an average value of daily production fluids in the last 3 months, or may be set according to actual conditions.
An IPR Curve (Inflow Performance Relationship Curve) is plotted according to equation (8) to determine the predicted production at the bottom hole flow pressure. Thus, the yield can be reasonably and reliably planned and predicted, and a tamping foundation is provided for screening the screw pump 206, the submersible motor 203 and the like.
After obtaining the pump suction pressure and the predicted production of the well, the progressive cavity pump data is obtained to screen the type of progressive cavity pump 206, wherein the progressive cavity pump data includes the actual displacement of the progressive cavity pump 206 and the head of the progressive cavity pump 206. The screw pump data is obtained as follows:
in a first step, the displacement of the screw pump 206 is determined.
Specifically, the theoretical displacement of the screw pump can be obtained according to the displacement per revolution of the screw pump and the rotating speed of the screw pump; obtaining actual output according to the theoretical displacement and the pump efficiency of the screw pump; and if the target actual output is not less than the predicted output, determining the theoretical displacement of the screw pump corresponding to the target actual output as the actual displacement of the screw pump.
Specifically, the actual displacement of the progressive cavity pump 206 is estimated based on the predicted production so that the progressive cavity pump 206 meets the well displacement requirements. The screw pump 206 is a speed-adjustable running pump, and the theoretical displacement of the screw pump is calculated by the following formula:
Q＝1440×q b ×n×10 -6 (9)；
wherein Q is the theoretical displacement of the screw pump, m 3 /d；q b The displacement per revolution of the screw pump is ml/r; n is the rotating speed of the screw pump, r/min.
The actual yield is calculated by the following formula:
Q fact = Q × η (10); wherein Q is fact For practical yield, η is the pumping efficiency of the screw pump 206 at the pumping depth,%.
In view of the spiral shellThe rod pump 206 has a pumping efficiency problem because of a leakage amount due to different submergence pressures during operation. After the predicted yield is determined, the requirement that Q multiplied by eta is more than or equal to Q is met max And the conditions are set to meet the requirements of oil production units. Therefore, Q fact ≥q max Then Q is turned on fact Determined as the actual displacement of the screw pump 206.
Second, the head of the screw pump 206 is determined.
Specifically, the total dynamic pressure of the screw pump 206 can be obtained according to the pump hanging depth, the oil pressure conversion pressure head, the oil pipe friction loss pressure head and the pump suction inlet pressure conversion pressure head of the screw pump 206; and if the target lift is not less than the total dynamic pressure head, determining that the target lift is the lift of the screw pump 206, wherein the target lift is the lifting height of the screw pump 206.
Specifically, in order to ensure that the electric submersible screw pump can lift crude oil to the ground, the total dynamic pressure head must be overcome, namely Hs is more than or equal to H. Wherein Hs is the head 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:
H＝H d +p o +F t -p p (11)；
wherein H is the total dynamic head of the screw pump 206, m; h d Is the pump hanging depth, m; p is a radical of o M is an oil pressure conversion pressure head; f t Is the pressure head of the abrasion resistance loss of the oil pipe, m; p is a radical of p Is the pump suction pressure converted head, m.
When the target head is not less than the total dynamic pressure, which also indicates that the minimum value of the target head is equal to the total dynamic pressure, the target head is determined as the head of the screw pump 206.
In the embodiment of the present disclosure, the screw pump 206 is divided into a rubber screw pump and an all-metal screw pump, the monopole head of the normal rubber screw pump is 500m, and the monopole pressure-bearing capacity of the metal screw pump is 300m, so the head (stage number) of the rubber screw pump can be determined by the following formula:
Figure BDA0003037500070000131
wherein, L is the rubber screw pump stage number, and H is the total dynamic pressure head.
In this step, the screw pump data is obtained based on the pump inlet pressure and the predicted production, providing a reliable and accurate basis for optimizing the appropriate type of screw pump 206.
After acquiring the screw pump data, step S102 is executed to acquire motor data of the submersible motor 203 according to the screw pump data, where the motor data includes a torque of the submersible motor 203 and a shaft power of the submersible motor 203.
Specifically, from the progressive cavity pump data, the type of submersible motor 203 is determined, further requiring the determination of the torque and shaft power of the submersible motor 203. The process of obtaining motor data is as follows:
in the first step, the torque of submersible motor 203 is determined.
Specifically, the screw pump 206 lifts the crude oil by rotation, and therefore the torque of the submersible motor 203 must be larger than the torque corresponding to the minimum head of the screw pump 206, and the torque of the submersible motor 203 is obtained from the driving torque at zero head and the head of the screw pump 206. The torque characteristic curve of the submersible motor 203 is an approximate curve which increases along with the increase of pressure and is calculated according to the following formula;
M＝M 0 +a·H s (13)；
wherein M is the torque of the submersible motor 203, N · M; m is a group of 0 Is the driving torque at zero head, N · m; a is the torque coefficient of a unit lifting pressure head of the screw pump, N.m/MPa.
In the embodiment of the present specification, when the selected submersible motor 203 is suspended by a specified pump, the torque M 'of the submersible motor 203 needs to be selected to be not less than M, that is, M' is not less than M.
And secondly, determining the shaft power of the submersible motor 203.
Specifically, the crude oil can be lifted by the screw pump 206 according to the pumping depth of the oil well, and the axial power of the submersible motor 203 is obtained according to the actual displacement of the screw pump 206, the lift of the screw pump 206, the average relative density of well fluid of the oil well and the pumping efficiency, and the specific formula is as follows:
Figure BDA0003037500070000141
wherein, N is the shaft power, KW, of the submersible motor 203 in the lifting process; gamma ray 1 Is the average relative density of the well fluid.
Specifically, the power of the motor protector 204 configured to the submersible motor 203 needs to be considered, and 1.5KW needs to be added to the submersible motor 203, so that the power of the submersible motor 203 is: (N + 1.5) KW, and in order to meet the requirements of special well conditions (such as sand sticking pump, wax deposition blockage, etc.), the calculated shaft power of the submersible motor 203 needs to be increased by a safety factor of 1.5 times, that is, (N + 1.5) × 1.5KW is used as the preferred rated power of the submersible motor 203.
The step fully considers and utilizes the screw pump data to design the submersible motor 203 data so as to ensure the reliability and the accuracy of the motor data.
After obtaining the motor data, step S103 is executed to obtain cable data of the submersible cable 207 according to the well temperature and the motor data. The cable data includes, among other things, the type of submersible cable 207, the length of submersible cable 207, the pressure drop loss and the power loss of submersible cable 207.
Specifically, the model of the submersible cable 207 is determined from 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. For example, the submersible motor brand ott pump industry, serial No.: 375. 456, 540, 562, 738; the national standard type: YQY; outer diameter: 98. 116, 143, 188 in mm; rated voltage: 380V-3000V; rated frequency: 50HZ (60 HZ customizable); 50Hz power range: 4.7KW-1008KW;60HZ power range 7.5-1620HP; the motor structure: single section, double section and three sections.
Specifically, the length of submersible cable 207 may be determined based on the pump hanging depth, indicating that submersible cable 207 length is no less than the pump hanging depth.
Specifically, since there is a voltage drop loss and a power loss in any cable, the voltage drop loss and the power loss of the submersible cable 207 can be determined according to the length of the submersible cable 207 and the model of the submersible cable 207. The pressure drop loss and power loss of submersible cable 207 are calculated as follows:
Figure BDA0003037500070000151
wherein Δ U is the cable voltage drop loss, V; sin phi is the reactive power coefficient; i is the rated current of the submersible motor 203, a; cos phi is the power factor; l is c Is the cable length, i.e. the pump hanging depth, m; r is the internal resistance, Ω, of the submersible cable 207; r is the conductor effective impedance and omega/kmX is the conductor reactance, omega/km.
ΔP＝3I 2 R×10 -3 (16)；
Wherein, Δ P is the power loss of the submersible cable 207, kW.
Next, step S104 is executed to obtain the cabinet-machine data of the control cabinet 212 according to the motor data, the cable data and the wellhead environment data of the oil well.
It should be explained that wellhead environment data includes: the geographic location of the wellhead, the weather of the wellhead, the area size of the wellhead, the reinjection at the wellhead and key equipment for safe production, a casing head, a tubing head, a Christmas tree and the like.
Specifically, the control cabinet 212 needs to consider the pressure drop loss and the power loss of the submersible cable 207, and ensure that the electric energy can be sent to the submersible motor 203, so that the submersible motor 203 is started; and the selection is carried out according to wellhead environment data, field 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 by the ground, and the control cabinet 212 has the function of adjusting the power supply frequency in real time, so that the rotating speed of the underground unit is adjusted, and the oil well production and supply balance is realized.
And finally, executing step S105, 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.
Specifically, an electronic version or paper version of report of the electric submersible screw pump matched with the oil well is generated according to the screw pump data, the motor data, the cable data and the cabinet data, so that relevant petroleum personnel can review the report, and construction and petroleum exploitation can be carried out according to the reliable report.
One or more technical solutions in the embodiments of the present invention have at least the following technical effects or advantages:
according to the method, dynamic analysis is carried out through data collection of natural gas data, crude oil data, water content data, historical yield of an oil well, oil well pressure and the like in the oil well, and screw pump data, motor data, cable data and cabinet machine data are obtained, so that proper production allocation of a screw pump, an oil-submersible motor, an oil-submersible cable and a control cabinet is determined, the discharge capacity and the lift of the screw pump are optimized, motor shaft power, cables, the control cabinet and other electrical parameters are determined, optimal well selection of the electric submersible screw pump is achieved, the applicability of the electric submersible screw pump is improved, oil well production balance is achieved, and the pump detection period of the oil well is prolonged.
Example two
Based on the same inventive concept, a second embodiment of the present invention further provides a device for determining well selection of an electric submersible screw pump, as shown in fig. 3, including:
a screw pump data module 301, configured to obtain screw pump data according to a pump suction pressure of the screw pump and a predicted yield of the oil well, where the pump suction pressure is obtained according to natural gas data, crude oil data, and water content data in the oil well, and the predicted yield is obtained according to a historical yield and a historical pressure of the oil well;
a motor data module 302, configured to obtain motor data of the submersible motor according to the screw pump data;
the cable data module 303 is used for acquiring cable data of the submersible cable according to the oil well temperature and the motor data;
a cabinet data module 304, configured to obtain cabinet data of the control cabinet according to the motor data, the cable data, and wellhead environment data of the oil well;
a production module 305 for determining a report of the electric submersible screw pump matched to the oil well based on the screw pump data, the motor data, the cable data and the cabinet data.
As an alternative embodiment, the progressive cavity pump data module 301 is further configured to obtain the pump suction pressure, and the obtaining step includes:
measuring pressure values of a plurality of pump suction inlets through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected with the submersible motor;
obtaining a 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-containing data and each pump suction inlet pressure value, and obtaining a corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio;
according to a target pump suction inlet gas-liquid ratio, searching a pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio to determine the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within a gas-liquid ratio threshold range.
As an optional embodiment, the obtaining, according to the natural gas data, the crude oil data, the water content data, and each of the pump suction inlet pressure values, a pump suction inlet gas-liquid ratio corresponding to each of the pump suction inlet pressure values, and obtaining a corresponding relationship between each of the pump suction inlet pressure values and a corresponding pump suction inlet gas-liquid ratio includes:
obtaining a saturated dissolved gas-oil ratio at a saturation pressure according to the natural gas relative density in the natural gas data, the crude oil relative density in the crude oil data, the saturation 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 pressure value of the pump suction inlet and the saturation pressure;
obtaining the volume coefficient of natural gas according to the temperature of the pump hanging position of the screw pump and the pressure value of the pump suction inlet;
obtaining the oil layer crude oil volume coefficient according to the natural gas relative density, the crude oil relative density and the corrected dissolved gas-oil ratio;
obtaining the gas-liquid ratio of the corresponding pump suction inlet according to the production gas-oil ratio, the water content of the water-containing data, the corrected dissolved gas-oil ratio, the volume coefficient of the natural gas, the volume coefficient of the oil-gas-water mixture of the pump suction inlet of the screw pump and the volume coefficient of the crude oil of the oil layer;
and obtaining the corresponding relation according to the pressure value of each suction inlet and the gas-liquid ratio of the corresponding pump suction inlet.
As an alternative embodiment, the screw pump data module 301 is further configured to obtain the predicted production, and the obtaining step includes:
obtaining the projected production from a formation pressure of the well, a bottom hole flow pressure of the well, and a well production in the historical production.
As an alternative embodiment, the obtaining progressive cavity pump data based on a pump suction pressure of the progressive cavity pump and a predicted production rate of the well comprises:
obtaining the theoretical displacement of the screw pump according to the displacement per revolution of the screw pump and the rotating speed of the screw pump;
obtaining actual output according to the theoretical displacement and the pump efficiency of the screw pump;
if the target actual output is not smaller than the predicted output, determining the theoretical displacement of the screw pump corresponding to the target actual output as the actual displacement of the screw pump;
obtaining a total dynamic pressure head of the screw pump according to the pump hanging depth, the oil pressure conversion pressure head, the oil pipe friction loss pressure head and the pump suction inlet pressure conversion pressure head of the screw pump;
and if the target lift is not smaller than the total dynamic pressure head, determining that the target lift is the lift of the screw pump, wherein the target lift is the lifting height of the screw pump, and the screw pump data comprises the lift of the screw pump and the actual discharge capacity of the screw pump.
As an optional embodiment, the obtaining motor data of the submersible motor according to the screw pump data includes:
obtaining the torque of the submersible motor according to the driving torque under the zero pressure head and the lift of the screw pump;
and obtaining the shaft power of the submersible motor according to the actual discharge capacity of the screw pump, the lift of the screw pump, the average relative density of well fluid of the oil well and the pump efficiency, wherein the motor data comprise the torque of the submersible motor and the shaft power of the submersible motor.
As an alternative embodiment, the obtaining the cable data of the submersible cable according to the well temperature and the motor data comprises:
determining the type 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 hanging depth;
obtaining the pressure drop loss and the 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 comprises the type of the submersible cable, the length of the submersible cable, and the voltage drop loss and power loss of the submersible cable.
Since the device for determining the well selection of the electric submersible screw pump described in this embodiment is a device used for implementing the method for determining the well selection of the electric submersible screw pump described in the first embodiment of this application, a person skilled in the art can understand the specific implementation manner of the device for determining the well selection of the electric submersible screw pump described in this embodiment and various variations thereof based on the method for determining the well selection of the electric submersible screw pump described in the first embodiment of this application, and therefore, how to implement the method in the first embodiment of this application for the device for determining the well selection of the electric submersible screw pump will not be described in detail herein. The device used by those skilled in the art to implement the method for determining the well selection of the electric submersible screw pump in the first embodiment of the present application is within the scope of the present application.
EXAMPLE III
Based on the same inventive concept, the third embodiment of the present invention further provides a computer apparatus, as shown in fig. 4, comprising a memory 404, a processor 402, and a computer program stored on the memory 404 and executable on the processor 402, wherein the processor 402 executes the program to implement the steps of any one of the above-mentioned methods for determining a selected well of an electric submersible progressive cavity pump.
Wherein in fig. 4 a bus architecture (represented by bus 400), bus 400 may include any number of interconnected buses and bridges, bus 400 linking together various circuits including one or more processors, represented by processor 402, and memory, represented by memory 404. The bus 400 may also link together various other circuits such as peripherals, voltage regulators, power management circuits, and the like, which are well known in the art, and therefore, will not be described any further herein. A bus interface 406 provides an interface between the bus 400 and the receiver 401 and transmitter 403. The receiver 401 and the transmitter 403 may be the same element, i.e., a transceiver, providing a means for communicating with various other apparatus over a transmission medium. The processor 402 is responsible for managing the bus 400 and general processing, while the memory 404 may be used for storing data used by the processor 402 in performing operations.
Example four
Based on the same inventive concept, a fourth embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored, which when executed by a processor, implements the steps of any one of the methods for determining a well selection of an electric submersible screw pump described in the previous embodiment.
As will be appreciated by one skilled in the art, embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
While preferred embodiments of the present invention have been described, additional variations and modifications in those embodiments may occur to those skilled in the art once they learn of the basic inventive concepts. Therefore, it is intended that the appended claims be interpreted as including the preferred embodiment and all changes and modifications that fall within the scope of the invention.
It will be apparent to those skilled in the art that various changes and modifications may be made in the present invention without departing from the spirit and scope of the invention. Thus, if such modifications and variations of the present invention fall within the scope of the claims of the present invention and their equivalents, the present invention is also intended to include such modifications and variations.

Claims (14)

1. The utility model provides a method for confirming that well selection is gone wrong to electric latent screw pump, is applied to electric latent screw pump, electric latent screw pump includes screw pump, submersible motor, dive the oil cable and switch board, the switch board pass through the cable of diving with submersible motor connects, submersible motor still with the screw pump is connected, its characterized in that, the method includes:
obtaining progressive cavity pump data based on pump inlet pressure of the progressive cavity pump and predicted production of the well, wherein the pump inlet pressure is obtained based on natural gas data, crude oil data, and water data in the well, and the predicted production is obtained based on historical production and historical pressure of the 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;
acquiring cabinet machine data of the control cabinet according to the motor data, the cable data and 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.
2. The method of claim 1, wherein said step of obtaining pump suction pressure comprises:
measuring pressure values of a plurality of pump suction inlets by a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected with the submersible motor;
obtaining a 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-containing data and each pump suction inlet pressure value, and obtaining a corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio;
and finding a pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio according to the target pump suction inlet gas-liquid ratio, and determining the pump suction inlet pressure as the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within the gas-liquid ratio threshold range.
3. The method of claim 2, wherein obtaining a pump intake gas-liquid ratio for each of the pump intake pressure values from the natural gas data, the crude oil data, the water content data, and each of the pump intake pressure values, and obtaining a correspondence between each of the pump intake pressure values and the corresponding pump intake gas-liquid ratio comprises:
obtaining a saturated dissolved gas-oil ratio at a saturation pressure according to the natural gas relative density in the natural gas data, the crude oil relative density in the crude oil data, the saturation 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 pressure value of the pump suction inlet and the saturation pressure;
obtaining the volume coefficient of natural gas according to the temperature of the pump hanging position of the screw pump and the pressure value of the pump suction inlet;
obtaining the oil layer crude oil volume coefficient according to the natural gas relative density, the crude oil relative density and the corrected dissolved gas-oil ratio;
obtaining the gas-liquid ratio of the corresponding pump suction inlet according to the production gas-oil ratio, the water content of the water-containing data, the corrected dissolved gas-oil ratio, the volume coefficient of the natural gas, the volume coefficient of the oil-gas-water mixture of the pump suction inlet of the screw pump and the volume coefficient of the crude oil in the oil layer;
and obtaining the corresponding relation according to the pressure value of each suction inlet and the gas-liquid ratio of the corresponding pump suction inlet.
4. The method of claim 3, wherein said projected production obtaining step comprises:
obtaining the projected production from a formation pressure of the well, a bottom hole flow pressure of the well, and a well production in the historical production.
5. The method of claim 4, wherein obtaining progressing cavity pump data based on pump inlet pressure of the progressing cavity pump and predicted production from the well comprises:
obtaining the theoretical displacement of the screw pump according to the displacement per revolution of the screw pump and the rotating speed of the screw pump;
obtaining actual output according to the theoretical displacement and the pump efficiency of the screw pump;
if the target actual output is not smaller than the predicted output, determining the theoretical displacement of the screw pump corresponding to the target actual output as the actual displacement of the screw pump;
obtaining a total dynamic pressure head of the screw pump according to the pump hanging depth, the oil pressure conversion pressure head, the oil pipe friction loss pressure head and the pump suction inlet pressure conversion pressure head of the screw pump;
and if the target lift is not smaller than the total dynamic pressure head, determining that the target lift is the lift of the screw pump, wherein the target lift is the lifting height of the screw pump, and the screw pump data comprises the lift of the screw pump and the actual discharge capacity of the screw pump.
6. The method of claim 5, wherein obtaining motor data for the submersible motor from the progressive cavity pump data comprises:
obtaining the torque of the submersible motor according to the driving torque under the zero pressure head and the lift of the screw pump;
and obtaining the shaft power of the submersible motor according to the actual discharge capacity of the screw pump, the lift of the screw pump, the average relative density of well fluid of the oil well and the pump efficiency, wherein the motor data comprises the torque of the submersible motor and the shaft power of the submersible motor.
7. The method of claim 6, wherein obtaining the wireline data for the submersible cable based on the well temperature and the motor data comprises:
determining the type 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 hanging depth;
obtaining the pressure drop loss and the 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 comprises the type of the submersible cable, the length of the submersible cable, and the voltage drop loss and power loss of the submersible cable.
8. The utility model provides a confirming device that electrical submersible screw pump selected well, is applied to electrical submersible screw pump, electrical submersible screw pump includes screw pump, dive the oily motor, dive oily cable and switch board, the switch board passes through dive oily cable with it connects to dive oily motor, dive oily motor still with the screw pump is connected, its characterized in that, the device includes:
the screw pump data module is used for obtaining screw pump data according to the pressure of a pump suction inlet of the screw pump and the predicted yield of the oil well, wherein the pressure of the pump suction inlet is obtained according to natural gas data, crude oil data and water-containing data in the oil well, and the predicted yield is obtained according to historical yield and historical pressure of the oil well;
the motor data module is used for acquiring motor data of the submersible motor according to the screw pump data;
the cable data module is used for obtaining the cable data of the submersible cable according to the oil well temperature and the motor data;
the cabinet machine data module is used for acquiring cabinet machine data of the control cabinet according to the motor data, the cable data and wellhead environment data of the oil well;
and the production module is used for determining the 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 machine data.
9. The apparatus of claim 8, wherein the screw pump data module is further to:
measuring pressure values of a plurality of pump suction inlets through a temperature and pressure measuring device, wherein the temperature and pressure measuring device is connected with the submersible motor;
obtaining a gas-liquid ratio of a pump suction inlet 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 a corresponding relation between each pump suction inlet pressure value and the corresponding gas-liquid ratio of the pump suction inlet;
according to a target pump suction inlet gas-liquid ratio, searching a pump suction inlet pressure value corresponding to the target pump suction inlet gas-liquid ratio from the corresponding relation between each pump suction inlet pressure value and the corresponding pump suction inlet gas-liquid ratio to determine the pump suction inlet pressure, wherein the target pump suction inlet gas-liquid ratio is within a gas-liquid ratio threshold range.
10. The apparatus of claim 9, wherein the screw pump data module is further to:
obtaining a saturated dissolved gas-oil ratio at a saturation pressure according to the natural gas relative density in the natural gas data, the crude oil relative density in the crude oil data, the saturation 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 pressure value of the pump suction inlet and the saturation pressure;
obtaining the volume coefficient of natural gas according to the temperature of the pump hanging position of the screw pump and the pressure value of the pump suction inlet;
obtaining the crude oil volume coefficient of an oil layer according to the natural gas relative density, the crude oil relative density and the corrected dissolved gas-oil ratio;
obtaining the gas-liquid ratio of the corresponding pump suction inlet according to the production gas-oil ratio, the water content of the water-containing data, the corrected dissolved gas-oil ratio, the volume coefficient of the natural gas, the volume coefficient of the oil-gas-water mixture of the pump suction inlet of the screw pump and the volume coefficient of the crude oil of the oil layer;
and obtaining the corresponding relation according to the pressure value of each suction inlet and the gas-liquid ratio of the corresponding pump suction inlet.
11. The apparatus of claim 10, wherein the screw pump data module is further to:
obtaining the projected production from a formation pressure of the well, a bottom hole flow pressure of the well, and a well production in the historical production.
12. The apparatus of claim 11, wherein the screw pump data module is further to:
obtaining the theoretical displacement of the screw pump according to the displacement per revolution of the screw pump and the rotating speed of the screw pump;
obtaining actual output according to the theoretical displacement and the pump efficiency of the screw pump;
if the target actual output is not smaller than the predicted output, determining the theoretical displacement of the screw pump corresponding to the target actual output as the actual displacement of the screw pump;
obtaining a total dynamic pressure head of the screw pump according to the pump hanging depth, the oil pressure conversion pressure head, the oil pipe friction loss pressure head and the pump suction inlet pressure conversion pressure head of the screw pump;
and if the target lift is not smaller than the total dynamic pressure head, determining that the target lift is the lift of the screw pump, wherein the target lift is the lifting height of the screw pump, and the screw pump data comprises the lift of the screw pump and the actual discharge capacity of the screw pump.
13. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the method steps of any of claims 1-7 when executing the program.
14. A computer-readable storage medium, on which a computer program is stored which, when being executed by a processor, carries out the method steps of any one of claims 1 to 7.
CN202110447759.4A 2021-04-25 2021-04-25 Method, device and equipment for determining well selection of electric submersible screw pump and storage medium Pending CN115324885A (en)

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CN202110447759.4A CN115324885A (en) 2021-04-25 2021-04-25 Method, device and equipment for determining well selection of electric submersible screw pump and storage medium

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