Single-well metering control method for oil well of oil and gas field based on localization of swan Mongolia system

Abstract

The invention discloses an oil-gas field oil well single-well metering control method based on the localization of a swan-Mongolia system, which realizes oil-gas field oil well single-well metering through an oil extraction metering control system constructed based on the swan-Mongolia system, and has higher flexibility and expansibility. A pump indicator diagram of the oil pumping unit is read and recognized to determine each first effective stroke of the oil pumping unit in unit time, the first effective strokes are further screened for the second time to obtain available second effective strokes meeting requirements, and finally effective liquid production capacities of the determined second effective strokes are accumulated to obtain the effective liquid production capacity of the oil pumping unit. According to the method, usability analysis is carried out on each stroke of the oil pumping unit in unit time, the metering defect that in the prior art, representative data are used for overall measurement and calculation is overcome, the effective liquid production capacity of each stroke of the oil pumping unit is determined by analyzing the water content of the output liquid production capacity, and the accuracy of measurement and calculation is improved. Therefore, the accuracy of metering the liquid production capacity of the oil well can be integrally improved.

Description

Technical Field

[0001] The present invention relates to the technical field of oilfield production management, and in particular to a method and device for controlling single-well metering in an oil and gas field based on the localization of the Hongmeng system, and a computer-readable storage medium. Background Art

[0002] For oil and gas field production, the measurement of oil well liquid production is an extremely important measurement parameter in the oil well exploitation process. How to conveniently and effectively measure the oil well liquid production is a major research topic in the current oil well industry. At present, for the convenience of measurement, the market usually uses a small number of sampled sucker rod stroke cycles as the basis, and selects one or two stroke cycles as representative data for overall measurement, thereby measuring the oil well liquid production. However, in the actual production environment, considering the influence of factors such as changes in pumping unit operating parameters, the instability of oil well exploitation environment, or differences in measurement methods, the liquid production in different stroke cycles is not necessarily similar. Therefore, measuring the oil well liquid production in the above manner will lead to large errors. Summary of the invention

[0003] The present invention aims to solve at least one of the technical problems in the related art to a certain extent. To this end, the present invention proposes a single well metering control method for oil and gas fields based on the localization of the Hongmeng system, which can improve the accuracy of the measurement of the liquid production of the oil well.

[0004] In the first aspect, an embodiment of the present invention provides a single-well metering control method for an oil and gas field based on the localization of the Hongmeng system, which is applied to an oil production metering control system constructed based on the Hongmeng system, wherein the oil production metering control system is connected to a correspondingly configured pumping unit, and the pumping unit is used to produce oil through an oil well; the method comprises the following steps: Step S1, obtaining a pump performance diagram of the oil pumping unit, reading load data and displacement data in the pump performance diagram of the oil pumping unit according to a preset sampling time sequence, so as to determine the change of the load data and the displacement data within a unit time; performing identification processing on the pump performance diagram of the oil pumping unit according to the change of the load data and the displacement data within a unit time, so as to determine a plurality of first effective strokes of the oil pumping unit within the unit time, wherein the unit time corresponds to the sampling time sequence; Step S2, for each first effective stroke of the oil pumping unit within the unit time, obtaining the pump fullness of the oil pumping unit within the first effective stroke and the corresponding oil well temperature parameter and oil well pressure parameter; calculating the stroke characteristic value of the first effective stroke according to the pump fullness, the oil well temperature parameter and the oil well pressure parameter; Step S3, performing secondary screening on each of the first effective strokes according to the stroke characteristic values ​​respectively corresponding to all the first effective strokes, so as to determine all the second effective strokes; Step S4, for each of the second effective strokes, obtaining the output liquid production of the second effective stroke; determining the effective liquid production of the second effective stroke according to the relative size relationship between the water content of the output liquid production and the first water content preset threshold value and the second water content preset threshold value, combined with the output liquid production of the second effective stroke; Step S5, accumulating the effective liquid production of all the second effective strokes to obtain the cumulative liquid production of the oil pump in the unit time.

[0005] Optionally, in one embodiment of the present invention, when the first water content preset threshold is less than the second water content preset threshold, the steps in step S4, according to the relative size relationship between the water content of the output liquid production and the first water content preset threshold and the second water content preset threshold, combined with the output liquid production of the second effective stroke, determine the effective liquid production of the second effective stroke, including the following steps: Step S41, when the water content of the output liquid production is less than the first water content preset threshold, determining that the effective liquid production of the second effective stroke is zero; or, When the water content of the output liquid production is greater than or equal to the first water content preset threshold and less than or equal to the second water content preset threshold, determining the effective liquid production of the second effective stroke as the output liquid production; or, When the water content of the output liquid production is greater than the second water content preset threshold, the leakage amount of the oil pump in the second effective stroke is obtained, and the change of the dynamic liquid level of the oil well in the second effective stroke is determined; based on the change of the dynamic liquid level, the leakage amount and the output liquid production, the effective liquid production of the second effective stroke is determined.

[0006] Optionally, in one embodiment of the present invention, when the water content of the output liquid production is greater than the second water content preset threshold, the steps in step S41, according to the dynamic liquid level change, the leakage amount and the output liquid production, determine the effective liquid production of the second effective stroke, including the following steps: Step S411, determining the dynamic change amplitude of the dynamic liquid level and the average rate of change of the dynamic liquid level within the second effective stroke according to the dynamic liquid level change; Step S412: Substitute the dynamic change amplitude of the dynamic liquid level, the average rate of change of the dynamic liquid level, the leakage amount and the output liquid production into the liquid production correction calculation formula to calculate the effective liquid production of the second effective stroke.

[0007] Optionally, in one embodiment of the present invention, the liquid production correction calculation formula in step S412 is as follows: ; in, is the effective liquid production of the second effective stroke, is the output liquid volume of the second effective stroke, is the leakage amount, is the average rate of change of the dynamic liquid surface, is the dynamic change amplitude of the dynamic liquid surface.

[0008] Optionally, in one embodiment of the present invention, the step in step S2, calculating the stroke characteristic value of the first effective stroke according to the pump fullness, the oil well temperature parameter and the oil well pressure parameter, comprises the following steps: Step S21, substituting the pump fullness, the oil well temperature parameter and the oil well pressure parameter into a preset stroke characteristic calculation formula to calculate the stroke characteristic value of the first effective stroke; wherein the stroke characteristic calculation formula is as follows: ; is the stroke characteristic value of the first effective stroke, is the oil well temperature parameter, is the oil well pressure parameter, is the pump fullness, Calculates the factor associated with the preset stroke.

[0009] Optionally, in one embodiment of the present invention, step S3 includes the following steps: Step S31: for each of the first effective strokes, determine whether the stroke characteristic value corresponding to the first effective stroke is not greater than a preset stroke characteristic threshold; if so, take the first effective stroke as one of the second effective strokes; otherwise, screen out the first effective stroke.

[0010] Optionally, in one embodiment of the present invention, the steps in step S1, according to the changes of the load data and the displacement data in a unit time, identify the pump work diagram of the pumping unit, so as to determine a plurality of first effective strokes of the pumping unit in the unit time, include the following steps: Step S11, determining the maximum load parameter of the oil well according to the changes of the load data and the displacement data within a unit time; Step S12, extracting features of the pump work diagram of the oil pumping unit according to the maximum load parameter, thereby generating a plurality of different feature work diagrams; Step S13, identifying and calculating each characteristic work diagram respectively, so as to obtain each first effective stroke of the oil pumping unit within the unit time.

[0011] Optionally, in one embodiment of the present invention, the step S5 further includes the following steps: Step S6: when it is determined that the accumulated liquid production is less than or equal to a preset liquid production threshold, obtaining the real-time motor power of the oil pumping unit; Step S7, determine whether the real-time motor power reaches the preset oil pumping balance power, if so, balance and adjust the operating strokes of the oil pumping unit based on the real-time motor power, otherwise increase the real-time motor power to the preset oil pumping balance power.

[0012] In the second aspect, an embodiment of the present invention provides a single well metering control device for oil and gas fields based on the localization of the Hongmeng system, including: at least one processor; at least one memory for storing at least one program; When at least one of the programs is executed by at least one of the processors, the oil and gas field single well metering control method based on the localization of the Hongmeng system as described in the first aspect is implemented.

[0013] In the third aspect, an embodiment of the present invention provides a computer-readable storage medium, which stores a program executable by a processor. When the program executable by the processor is executed by the processor, it is used to implement the oil and gas field single well metering control method based on the localization of the Hongmeng system as described in the first aspect.

[0014] The oil and gas field single well metering control method based on the localization of the Hongmeng system proposed in the present invention realizes the single well metering of oil and gas fields through the oil production metering control system constructed based on the Hongmeng system, which has greater flexibility and scalability. Specifically, the oil production metering control system reads and identifies the pump power diagram of the oil pumping unit, so as to determine the first effective strokes of the oil pumping unit in unit time, and further obtains the corresponding second effective stroke by secondary screening through the stroke characteristic values ​​corresponding to each first effective stroke, and the second effective stroke is the available stroke of the oil pumping unit in the unit time corresponding to the sampling time series. Finally, by determining the effective liquid production of each second effective stroke and accumulating the effective liquid production of each second effective stroke, the cumulative liquid production of the oil pump in unit time can be obtained. It can be seen that not only the availability analysis is performed separately for each stroke of the oil pump in unit time, avoiding the metering defects of using representative data for overall measurement in the relevant existing technology, which can improve the accuracy of oil well liquid production metering, but also the correlation threshold analysis of the water content of the output liquid production is used to determine the effective liquid production of each stroke of the oil pump in unit time, thereby further improving the accuracy of oil well liquid production metering. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] Figure 1 It is a flow chart of a single well metering control method for oil and gas field oil wells based on the localization of the Hongmeng system provided by an embodiment of the present invention; Figure 2 yes Figure 1 A partial flow chart of the step S1 of "performing identification processing on the pumping diagram of the oil pumping unit according to the change of the load data and the displacement data within the unit time, thereby determining a plurality of first effective strokes of the oil pumping unit within the unit time"; Figure 3 yes Figure 1 Flow chart of step S3 in FIG. Figure 4 yes Figure 1 Partial flow chart of the step S4 of "determining the effective liquid production of the second effective stroke in combination with the output liquid production of the second effective stroke according to the relative magnitude relationship between the water content of the output liquid production and the first water content preset threshold value and the second water content preset threshold value"; Figure 5 yes Figure 4 A partial flow chart of the step S41 in step "determining the effective liquid production of the second effective stroke according to the dynamic liquid level change, the leakage amount and the output liquid production"; Figure 6 It is a flow chart of a single well metering control method for oil and gas fields based on the localization of the Hongmeng system provided by another embodiment of the present invention; Figure 7It is a structural schematic diagram of a single-well metering control device for an oil and gas field based on the localization of the Hongmeng system provided by one embodiment of the present invention. DETAILED DESCRIPTION

[0016] like Figure 1 As shown, an embodiment of the present invention provides a single-well metering control method for an oil and gas field based on the localization of the Hongmeng system. The method can be, but is not limited to, applied to an oil production metering control system constructed based on the Hongmeng system. The oil production metering control system is connected to a correspondingly configured oil pump, which is used to produce oil through the oil well. Specifically, it can include, but is not limited to, steps S1 to S5; wherein the oil production metering control system in this embodiment can be, but is not limited to, built based on the localization of the open source Hongmeng system. For example, the hardware architecture and software architecture associated with the oil production metering control system can be built based on the microkernel of the open source Hongmeng system, thereby realizing a system based on The construction of the associated architecture for the localization of the Hongmeng system can be understood as measuring and controlling individual oil wells in oil and gas fields through the efficient computing environment and stable data logic framework provided by the open source Hongmeng system, thereby improving the accuracy of the measurement of oil well liquid production. Since the Hongmeng system is a distributed operating system well known to those skilled in the art, the localized Hongmeng system will not be elaborated here to avoid redundancy. The specific architecture and parameters of the oil production metering control system built based on the Hongmeng system can be set as needed. There is no restriction here. It is only necessary to ensure that it is applied to the individual oil well metering control method in the oil and gas field provided in this embodiment.

[0017] Step S1, obtaining a pump performance diagram of the oil pumping unit, reading load data and displacement data in the pump performance diagram of the oil pumping unit according to a preset sampling time sequence to determine the change of the load data and the displacement data within a unit time; performing identification processing on the pump performance diagram of the oil pumping unit according to the change of the load data and the displacement data within a unit time, thereby determining a plurality of first effective strokes of the oil pumping unit within a unit time, wherein the unit time corresponds to the sampling time sequence; It should be noted that in different actual application scenarios, the specific parameters and configuration methods of the sampling time series and unit time may be different, and are set accordingly according to the actual application scenarios. For example, it is possible but not limited to performing data sensing and collection on oil wells in different dimensions, so as to obtain sampling data of various types or under various application conditions, and then determine the sampling time series according to the duration of the data sampling. The unit time can be selected as any sampling time included in the sampling time series, such as the maximum duration of the data sampling can be used as the unit time, etc., which is not limited here; It can be understood that, since the sampling time series and its corresponding time duration are determined, and the pump performance diagram of the oil pumping unit is known, the load data and displacement data in the pump performance diagram of the oil pumping unit can be read based on the sampling time series, that is, all the load data and displacement data corresponding to the relevant part of the sampling time series in the pump performance diagram of the oil pumping unit can be read, so that the change of the load data and displacement data in unit time can be determined based on all the read load data and displacement data; Step S2: for each first effective stroke of the oil pumping unit within a unit time, obtain the pump fullness of the oil pumping unit within the first effective stroke and the corresponding oil well temperature parameter and oil well pressure parameter; calculate the stroke characteristic value of the first effective stroke according to the pump fullness, oil well temperature parameter and oil well pressure parameter, wherein the specific number of the first effective stroke is not limited and needs to be specifically analyzed and determined according to the sampling time sequence and the pump work diagram of the oil pumping unit, but no matter how much the number is, the single well metering control method of the oil and gas field oil well of this embodiment can be applied; Step S3, performing secondary screening on each first effective stroke according to the stroke characteristic values ​​respectively corresponding to all first effective strokes, so as to determine all second effective strokes; Step S4, for each second effective stroke, obtaining the output liquid production of the second effective stroke; determining the effective liquid production of the second effective stroke according to the relative size relationship between the water content of the output liquid production and the first water content preset threshold value and the second water content preset threshold value, combined with the output liquid production of the second effective stroke, wherein the specific parameters of the first water content preset threshold value and the second water content preset threshold value and the size relationship between the two can be set accordingly according to the actual application scenario, and are not limited here; Step S5, accumulating the effective liquid production of all the second effective strokes to obtain the cumulative liquid production of the oil pumping unit per unit time.

[0018] In this step, the single-well metering of oil and gas fields is realized through the oil production metering control system built based on the Hongmeng system, which has greater flexibility and scalability. Specifically, the oil production metering control system reads and identifies the pump power diagram of the oil pumping unit, so as to determine the first effective strokes of the oil pumping unit in unit time, and further obtains the corresponding second effective strokes through secondary screening of the stroke characteristic values ​​corresponding to each first effective stroke. The second effective stroke is the available stroke of the oil pumping unit in the unit time corresponding to the sampling time series. Finally, by determining each second effective stroke The effective liquid production of each stroke can be obtained by accumulating the effective liquid production of each second effective stroke to obtain the cumulative liquid production of the oil pump per unit time. It can be seen that not only the availability analysis is performed separately for each stroke of the oil pump per unit time, avoiding the metering defect of using representative data for overall measurement in the related existing technology, which can improve the accuracy of oil well liquid production metering, but also the correlation threshold analysis of the water content of the output liquid production is used to determine the effective liquid production of each stroke of the oil pump per unit time, thereby further improving the accuracy of oil well liquid production metering.

[0019] like Figure 2 As shown, in one embodiment of the present invention, the steps in step S1, according to the change of load data and displacement data in unit time, the pump work diagram of the pumping unit is identified and processed, so as to determine a plurality of first effective strokes of the pumping unit in unit time, specifically may include but is not limited to the following steps: Step S11, determining the maximum load parameter of the oil well according to the change of the load data and the displacement data in unit time; Step S12, extracting features of the pumping unit's pumping power diagram according to the maximum load parameter, thereby generating a plurality of different feature power diagrams; Step S13: performing identification and calculation on each characteristic work diagram respectively, so as to obtain each first effective stroke of the oil pumping unit within a unit time.

[0020] In this step, by analyzing the changes in load data and displacement data within a unit time, a comparison can be made between load data at different time nodes, thereby determining the maximum load parameter of the oil well. Since the maximum load parameter can best reflect the real-time changes in the oil well, the pump power diagram of the oil pump is further feature extracted based on the maximum load parameter, and multiple different characteristic power diagrams can be effectively extracted. Finally, each characteristic power diagram is identified and calculated separately, that is, a first effective stroke corresponding to the oil pump within a unit time can be determined based on each characteristic power diagram, thereby ultimately determining all first effective strokes of the oil pump within a unit time conveniently and reliably.

[0021] In one embodiment, the steps in step S13 can be performed in a variety of specific ways to identify and calculate each characteristic power diagram, which are not limited here. For example, if one of the characteristic power diagrams presents an unsaturated U-shaped state, then the first effective stroke can be determined by identifying multiple groups of spatial points therein, and each group of spatial points can represent stroke-related information such as time nodes and loads. The effective stroke length can be determined by combining the stroke-related information to determine the corresponding first effective stroke. By analogy, when the characteristic power diagram is also a quadrilateral, other shapes in which various states appear alternately, etc., the corresponding first effective stroke can be determined by similar calculation, which is not elaborated here.

[0022] In one embodiment of the present invention, the step in step S2, calculating the stroke characteristic value of the first effective stroke according to the pump fullness, the oil well temperature parameter and the oil well pressure parameter, comprises the following steps: Step S21, substituting the pump fullness, oil well temperature parameter and oil well pressure parameter into a preset stroke characteristic calculation formula to calculate the stroke characteristic value of the first effective stroke; the stroke characteristic calculation formula may be, but is not limited to, as shown below: ; in, is the stroke characteristic value of the first effective stroke, is the oil well temperature parameter, is the oil well pressure parameter, is the pump fullness, is the preset stroke correlation calculation factor, The specific value of can be set according to the actual application scenario. Preferably, The configuration is 2.5~4.5.

[0023] like Figure 3 As shown, in one embodiment of the present invention, step S3 may include but is not limited to the following steps: Step S31: for each first effective stroke, determine whether the stroke characteristic value corresponding to the first effective stroke is not greater than a preset stroke characteristic threshold; if so, take the first effective stroke as one of the second effective strokes; otherwise, screen out the first effective stroke.

[0024] In this step, the specific value of the preset stroke characteristic threshold can be set accordingly according to different scenarios. After the preset stroke characteristic threshold is determined, it is determined whether the stroke characteristic value corresponding to the first effective stroke is not greater than the preset stroke characteristic threshold. If so, it means that the stroke characteristic value corresponding to the first effective stroke meets the application requirements, and the first effective stroke is used as one of the second effective strokes. Otherwise, it means that the stroke characteristic value corresponding to the first effective stroke does not meet the application requirements, and the first effective stroke needs to be screened out. It can be seen that through this judgment method, the unusable strokes in each first effective stroke can be screened out and eliminated, so as to obtain the second effective stroke that meets the application requirements. In this way, the corresponding calculation can be performed based on the liquid production data of all the second effective strokes, and the calculation effect is better and the result is more accurate.

[0025] like Figure 4 As shown, in one embodiment of the present invention, when the first preset water content threshold is less than the second preset water content threshold, the steps in step S4, according to the relative size relationship between the water content of the output liquid production and the first preset water content threshold and the second preset water content threshold, combined with the output liquid production of the second effective stroke, determine the effective liquid production of the second effective stroke, which may include but is not limited to the following steps: Step S41, when the water content of the output liquid production is less than the first water content preset threshold, determine that the effective liquid production of the second effective stroke is zero; or, when the water content of the output liquid production is greater than or equal to the first water content preset threshold and less than or equal to the second water content preset threshold, determine that the effective liquid production of the second effective stroke is the output liquid production; or, when the water content of the output liquid production is greater than the second water content preset threshold, obtain the leakage of the pumping unit in the second effective stroke, and determine the change of the dynamic liquid level of the oil well in the second effective stroke, and determine the effective liquid production of the second effective stroke according to the change of the dynamic liquid level, the leakage and the output liquid production.

[0026] In this step, when the water content of the output liquid production is less than the first water content preset threshold, since the first water content preset threshold is used as the minimum water content limit value, it means that the water content of the output liquid production is in an abnormal state. At this time, it is very likely that there are unexpected situations such as measurement errors and leakage in the liquid production output pipeline. Therefore, it can be determined that the effective liquid production of the second effective stroke is zero; when the water content of the output liquid production is greater than or equal to the first water content preset threshold and less than or equal to the second water content preset threshold, it means that the water content of the output liquid production is within a normal threshold range and the accuracy is relatively high. Therefore, it can be determined that the output liquid production of the second effective stroke is the effective liquid production of the second effective stroke; when the water content of the output liquid production is greater than the second water content preset threshold, it means that the water content of the output liquid production is within a normal threshold range but the accuracy is relatively low. Therefore, according to the change of the dynamic liquid level, The output liquid production of the second effective stroke is corrected accordingly according to the condition, leakage and output liquid production, so as to determine the effective liquid production of the second effective stroke, wherein the leakage refers to the liquid flow rate lost due to leakage between the pump inlet and outlet, and its size depends on factors such as the structure, operating status and liquid properties of the pump, and to a certain extent characterizes the performance and efficiency of the pump; the oil pumping volume of the oil well is closely related to the dynamic liquid level, which refers to the depth of the liquid level from the ground to the wellbore, reflecting the relationship between the bottom hole flow pressure and the formation pressure. Generally speaking, the higher the dynamic liquid level, the greater the liquid column pressure and the higher the bottom hole flow pressure, which will lead to a decrease in the production of the oil well. In other words, the dynamic liquid level is a direct manifestation of the oil well's liquid supply capacity, and the change of the dynamic liquid level can directly affect the oil pumping volume of the oil well; therefore, according to the change of the dynamic liquid level, the leakage and output liquid production, the effective liquid production of the second effective stroke can be accurately and reliably determined.

[0027] like Figure 5 As shown, in one embodiment of the present invention, when the water content of the output liquid production is greater than the second water content preset threshold, the steps in step S41, according to the dynamic liquid level change, the leakage amount and the output liquid production, determine the effective liquid production of the second effective stroke, which may include but is not limited to the following steps: Step S411, determining the dynamic change amplitude of the dynamic liquid level and the average rate of change of the dynamic liquid level within the second effective stroke according to the change of the dynamic liquid level; Step S412: Substitute the dynamic change amplitude of the dynamic liquid level, the average rate of change of the dynamic liquid level, the leakage amount and the output liquid production into the liquid production correction calculation formula to calculate the effective liquid production of the second effective stroke.

[0028] In this step, the dynamic liquid level change can be determined based on the relevant data collected in the time sampling sequence. For example, the initial dynamic liquid level depth data is determined based on the dynamic output model in the relevant prior art, and then the specific change of the initial dynamic liquid level depth data is observed based on the relevant data collected in the time sampling sequence, so as to determine the change amplitude and specific change period of the dynamic liquid level depth data in this process, that is, to determine the dynamic change amplitude of the dynamic liquid level and the average rate of change of the dynamic liquid level in the second effective stroke. The dynamic change amplitude of the dynamic liquid level and the average rate of change of the dynamic liquid level well reflect the influence of the dynamic liquid level change on the liquid production. Then, the dynamic change amplitude of the dynamic liquid level, the average rate of change of the dynamic liquid level, the leakage amount and the output liquid production are substituted into the liquid production correction calculation formula for calculation, so as to obtain the corrected effective liquid production of the second effective stroke.

[0029] In one embodiment, the liquid production correction calculation formula in step S412 may be, but is not limited to, as follows: ; in, is the effective liquid production of the second effective stroke, is the output liquid volume of the second effective stroke, is the leakage amount, is the average velocity of the liquid surface change, is the dynamic change amplitude of the liquid surface.

[0030] like Figure 6 As shown, in one embodiment of the present invention, step S5 may further include but is not limited to the following steps: Step S6: when it is determined that the accumulated liquid production is less than or equal to the preset liquid production threshold, the real-time motor power of the oil pumping unit is obtained; Step S7, determine whether the real-time motor power reaches the preset oil pumping balance power. If so, balance and adjust the running strokes of the oil pumping unit based on the real-time motor power; otherwise, increase the real-time motor power to the preset oil pumping balance power.

[0031] In this step, it is determined whether the cumulative liquid production is less than or equal to the preset liquid production threshold. If so, it means that the cumulative liquid production of the oil pump has not reached the expectation. Therefore, it is necessary to regulate the factors affecting the cumulative liquid production of the oil pump. Specifically, the regulation is performed by obtaining the real-time motor power of the oil pump. The real-time motor power can better characterize the pumping operation of the oil pump. If it is determined that the real-time motor power reaches the preset pumping balance power, it means that the real-time motor power has met the pumping operation parameter requirements, but the cumulative liquid production is less than or equal to the preset liquid production threshold. In this case, it is necessary to balance and adjust the operating strokes of the oil pump based on the real-time motor power to achieve the optimization of the oil well liquid production. Otherwise, it means that the real-time motor power does not meet the pumping operation parameter requirements. Therefore, the real-time motor power can be increased to the preset pumping balance power to achieve the optimization of the oil well liquid production.

[0032] In one embodiment, there may be many specific ways to balance and adjust the operating strokes of the oil pump based on the real-time motor power, which are not limited here. For example, the corresponding balanced operating strokes of the oil pump are pre-set, and it is determined whether the operating strokes of the oil pump under the real-time motor power have reached the balanced operating strokes. If the balanced operating strokes are not reached, the real-time motor power is increased to a certain extent to increase the balanced operating strokes, making it easier to reach the balanced operating strokes. Otherwise, the real-time motor power is reduced to maintain the balance of the operating strokes of the oil pump. The specific value of the balanced operating strokes can be set accordingly according to different application scenarios, for example, by technical personnel in this field based on historical experience or statistical data.

[0033] Figure 7 This is a structural schematic diagram of a single well metering control device 1000 for an oil and gas field based on the localization of the Hongmeng system provided by an embodiment of the present invention. Figure 7 As shown, the localized oil and gas field single well metering control device 1000 based on the Hongmeng system includes a memory 1100 and a processor 1200. The number of the memory 1100 and the processor 1200 can be one or more. Figure 7 In the embodiment, a memory 1100 and a processor 1200 are taken as an example; the memory 1100 and the processor 1200 in the device may be connected via a bus or other means. Figure 7 The example of connecting through bus is taken in the following.

[0034] The memory 1100, as a computer-readable storage medium, can be used to store software programs, computer executable programs and modules, such as the program instructions / modules corresponding to the oil and gas field oil well single well metering control method based on the localization of the Hongmeng system provided in any embodiment of the present invention. The processor 1200 implements the above-mentioned oil and gas field oil well single well metering control method based on the localization of the Hongmeng system by running the software programs, instructions and modules stored in the memory 1100.

[0035] The memory 1100 may mainly include a program storage area and a data storage area, wherein the program storage area may store an operating system and an application required for at least one function. In addition, the memory 1100 may include a high-speed random access memory, and may also include a non-volatile memory, such as at least one disk storage device, a flash memory device, or other non-volatile solid-state storage device. In some instances, the memory 1100 may further include a memory remotely arranged relative to the processor 1200, and these remote memories may be connected to the device via a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and combinations thereof.

[0036] An embodiment of the present invention also provides a computer-readable storage medium storing computer-executable instructions, which are used to execute a localized single-well metering control method for oil and gas fields based on the Hongmeng system as provided in any embodiment of the present invention.

[0037] An embodiment of the present invention also provides a computer program product, including a computer program or computer instructions, which are stored in a computer-readable storage medium. The processor of a computer device reads the computer program or computer instructions from the computer-readable storage medium, and the processor executes the computer program or computer instructions, so that the computer device executes the localized single well metering control method for oil and gas field wells based on the Hongmeng system as provided in any embodiment of the present invention.

[0038] Those skilled in the art will appreciate that all or some of the steps in the methods disclosed above, and the functional modules / units in the systems and devices may be implemented as software, firmware, hardware, or a suitable combination thereof.

[0039] In hardware implementation, the division between the functional modules / units mentioned in the above description does not necessarily correspond to the division of physical components; for example, a physical component may have multiple functions, or a function or step may be performed by several physical components in cooperation. Some or all physical components may be implemented as software executed by a processor, such as a central processing unit, a digital signal processor, or a microprocessor, or implemented as hardware, or implemented as an integrated circuit, such as an application-specific integrated circuit. Such software may be distributed on a computer-readable medium, which may include a computer storage medium (or non-transitory medium) and a communication medium (or transient medium). As is well known to those of ordinary skill in the art, the term computer storage medium includes volatile and non-volatile, removable and non-removable media implemented in any method or technology for storing information (such as computer-readable instructions, data structures, program modules, or other data). Computer storage media include, but are not limited to, RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disk (DVD) or other optical disk storage, magnetic cassettes, magnetic tapes, disk storage or other magnetic storage devices, or any other medium that can be used to store desired information and can be accessed by a computer. Furthermore, it is well known to those skilled in the art that communication media typically embodies computer readable instructions, data structures, program modules, or other data in a modulated data signal such as a carrier wave or other transport mechanism, and may include any information delivery media.

[0040] The terms "component", "module", "system", etc. used in this specification are used to represent computer-related entities, hardware, firmware, a combination of hardware and software, software, or software in execution. For example, a component can be, but is not limited to, a process running on a processor, a processor, an object, an executable file, an execution thread, a program, or a computer. By way of illustration, both applications running on a computing device and a computing device can be components. One or more components may reside in a process or an execution thread, and a component may be located on a computer or distributed between two or more computers. In addition, these components may be executed from various computer-readable media having various data structures stored thereon. Components may communicate, for example, through local or remote processes based on signals having one or more data packets (e.g., data from two components interacting with another component between a local system, a distributed system, or a network, such as the Internet interacting with other systems through signals).

Claims

1. A single well metering control method for oil and gas fields based on the localization of the Hongmeng system, characterized in that: Applied to an oil production metering control system built based on the Hongmeng system, the oil production metering control system is connected to a correspondingly configured oil pumping unit, and the oil pumping unit is used to produce oil through an oil well; the method comprises the following steps: Step S1, obtaining a pump performance diagram of the oil pumping unit, reading load data and displacement data in the pump performance diagram of the oil pumping unit according to a preset sampling time sequence, so as to determine the change of the load data and the displacement data within a unit time; performing identification processing on the pump performance diagram of the oil pumping unit according to the change of the load data and the displacement data within a unit time, so as to determine a plurality of first effective strokes of the oil pumping unit within the unit time, wherein the unit time corresponds to the sampling time sequence; Step S2, for each first effective stroke of the oil pumping unit within the unit time, obtaining the pump fullness of the oil pumping unit within the first effective stroke and the corresponding oil well temperature parameter and oil well pressure parameter; calculating the stroke characteristic value of the first effective stroke according to the pump fullness, the oil well temperature parameter and the oil well pressure parameter; Step S3, performing secondary screening on each of the first effective strokes according to the stroke characteristic values ​​respectively corresponding to all the first effective strokes, so as to determine all the second effective strokes; Step S4, for each of the second effective strokes, obtaining the output liquid production of the second effective stroke; determining the effective liquid production of the second effective stroke according to the relative size relationship between the water content of the output liquid production and the first water content preset threshold value and the second water content preset threshold value, combined with the output liquid production of the second effective stroke; Step S5, accumulating the effective liquid production of all the second effective strokes to obtain the cumulative liquid production of the oil pump in the unit time.

2. According to the method for controlling the measurement of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 1, it is characterized in that: When the first water content preset threshold is less than the second water content preset threshold, the steps in step S4, according to the relative size relationship between the water content of the output liquid production and the first water content preset threshold and the second water content preset threshold, combined with the output liquid production of the second effective stroke, determine the effective liquid production of the second effective stroke, including the following steps: Step S41, when the water content of the output liquid production is less than the first water content preset threshold, determining that the effective liquid production of the second effective stroke is zero; or, When the water content of the output liquid production is greater than or equal to the first water content preset threshold and less than or equal to the second water content preset threshold, determining the effective liquid production of the second effective stroke as the output liquid production; or, When the water content of the output liquid production is greater than the second water content preset threshold, the leakage amount of the oil pump in the second effective stroke is obtained, and the change of the dynamic liquid level of the oil well in the second effective stroke is determined; based on the change of the dynamic liquid level, the leakage amount and the output liquid production, the effective liquid production of the second effective stroke is determined.

3. According to the method for controlling the measurement of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 2, it is characterized in that: When the water content of the output liquid production is greater than the second water content preset threshold, the steps in step S41, according to the dynamic liquid level change, the leakage amount and the output liquid production, determine the effective liquid production of the second effective stroke, including the following steps: Step S411, determining the dynamic change amplitude of the dynamic liquid level and the average rate of change of the dynamic liquid level within the second effective stroke according to the dynamic liquid level change; Step S412: Substitute the dynamic change amplitude of the dynamic liquid level, the average rate of change of the dynamic liquid level, the leakage amount and the output liquid production into the liquid production correction calculation formula to calculate the effective liquid production of the second effective stroke.

4. According to the method for controlling the metering of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 3, it is characterized in that: The liquid production correction calculation formula in step S412 is as follows: ； in, is the effective liquid production of the second effective stroke, is the output liquid volume of the second effective stroke, is the leakage amount, is the average rate of change of the dynamic liquid surface, is the dynamic change amplitude of the dynamic liquid surface.

5. According to the method for controlling the measurement of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 1, it is characterized in that: The step in step S2, calculating the stroke characteristic value of the first effective stroke according to the pump fullness, the oil well temperature parameter and the oil well pressure parameter, comprises the following steps: Step S21, substituting the pump fullness, the oil well temperature parameter and the oil well pressure parameter into a preset stroke characteristic calculation formula to calculate the stroke characteristic value of the first effective stroke; wherein the stroke characteristic calculation formula is as follows: ； is the stroke characteristic value of the first effective stroke, is the oil well temperature parameter, is the oil well pressure parameter, is the pump fullness, Calculates the factor associated with the preset stroke.

6. According to the method for controlling the measurement of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 1, it is characterized in that: The step S3 comprises the following steps: Step S31: for each of the first effective strokes, determine whether the stroke characteristic value corresponding to the first effective stroke is not greater than a preset stroke characteristic threshold; if so, take the first effective stroke as one of the second effective strokes; otherwise, screen out the first effective stroke.

7. According to the method for controlling the measurement of a single well in an oil and gas field based on the localization of the Hongmeng system according to claim 1, it is characterized in that: The step in step S1, according to the change of the load data and the displacement data in a unit time, performs identification processing on the pump work diagram of the pumping unit, thereby determining a plurality of first effective strokes of the pumping unit in the unit time, comprises the following steps: Step S11, determining the maximum load parameter of the oil well according to the changes of the load data and the displacement data within a unit time; Step S12, extracting features of the pump work diagram of the oil pumping unit according to the maximum load parameter, thereby generating a plurality of different feature work diagrams; Step S13, identifying and calculating each characteristic work diagram respectively, so as to obtain each first effective stroke of the oil pumping unit within the unit time.

8. The oil and gas field oil well single well metering control method based on the localization of the Hongmeng system according to any one of claims 1 to 7 is characterized in that: The step S5 further includes the following steps: Step S6: when it is determined that the accumulated liquid production is less than or equal to a preset liquid production threshold, obtaining the real-time motor power of the oil pumping unit; Step S7, determine whether the real-time motor power reaches the preset oil pumping balance power, if so, balance and adjust the operating strokes of the oil pumping unit based on the real-time motor power, otherwise increase the real-time motor power to the preset oil pumping balance power.

9. A single well metering control device for oil and gas fields based on the localization of Hongmeng system, characterized in that: include: at least one processor; at least one memory for storing at least one program; When at least one of the programs is executed by at least one of the processors, the oil and gas field single well metering control method based on the localization of the Hongmeng system is implemented.

10. A computer-readable storage medium, characterized in that: A processor-executable program is stored therein, and when the processor-executable program is executed by the processor, it is used to implement the oil and gas field single well metering control method based on the localization of the Hongmeng system as described in any one of claims 1 to 8.

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