A peak-valley flat electricity price pumping unit inter-pumping control method, device and equipment

Abstract

The application discloses a peak-valley flat electricity price pumping unit interval pumping control method and device and equipment. The method comprises the following steps: calculating the minimum stable pump efficiency in the peak section duration; obtaining the pumping efficiency at the pumping starting time, recording the pumping time until the pump efficiency reaches the minimum stable pump efficiency, and calculating the peak section interval pumping production duration; solving the valley flat section interval pumping production duration based on an interval pumping optimization model; if there is no initial solution, selecting the liquid production controllable coefficient in the preset value range in descending order and substituting it into the interval pumping optimization model to solve again; if there is still no solution, taking the peak section interval pumping production duration as the optimized valley flat section interval pumping production duration; if there is a solution, obtaining the optimized interval pumping system according to the solution of the interval pumping optimization model; if there is an initial solution, increasing the well shut-in duration in the preset well shut-in duration range according to the preset time step, and solving again until there is no solution or the well shut-in duration reaches the upper limit value of the well shut-in duration, and determining the optimized interval pumping system.

Description

Technical Field

[0001] This invention relates to the field of oilfield pumping unit manufacturing technology, and in particular to a method, device and equipment for controlling intermittent pumping of pumping units under peak-valley-flat electricity pricing. Background Technology

[0002] As oilfield development enters its mid-to-late stages, formation fluid supply capacity declines, leading to an increase in low-yield and inefficient wells. The continuous inefficient production of these wells inevitably results in energy waste. Furthermore, excessively low dynamic fluid levels, approaching dry pumping, cause dry wear on the pumping unit, leading to overheating of the polished rod and accelerated equipment aging. This results in increased downtime and maintenance costs. For wells with deep pump depths and dynamic fluid levels, where parameter adjustments cannot achieve coordinated and efficient production, intermittent pumping to restore fluid supply capacity and then resume efficient production has become the development direction. Taking a certain oilfield with over 6,500 pumping wells as an example, among the 6,200 wells in operation, 1,545 wells produce less than 3 tons of fluid per day, accounting for about one-quarter of the total. Of these 1,545 wells, over 700 have implemented intermittent pumping production. However, these intermittent pumping wells use a system that does not consider peak, valley, or flat electricity prices, resulting in random start-up and shutdown times. The same intermittent pumping strategy is used during peak and off-peak periods of industrial electricity prices. Summary of the Invention

[0003] To reduce production costs and improve production efficiency, this invention provides a method, apparatus, and equipment for controlling inter-pumping operations using peak-valley-flat electricity pricing.

[0004] In a first aspect, embodiments of the present invention provide a method for controlling inter-unit pumping under peak-valley-flat electricity pricing, which may include:

[0005] During the peak period, dynamometer diagrams of the target well during continuous pumping within a preset time length are collected, and the minimum stable pump efficiency is calculated based on the collected dynamometer diagrams.

[0006] When pumping is started after the initial shutdown time of the target well, the pumping efficiency at the start time is obtained, the dynamometer is collected and the pumping efficiency is calculated according to the preset time interval, the pumping time until the pumping efficiency reaches the minimum stable pumping efficiency is recorded, and the peak-segment pumping production time is calculated.

[0007] Based on the peak duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the peak inter-pumping production duration, the valley-level inter-pumping production duration is solved using an inter-pumping optimization model.

[0008] If there is no initial solution, the controllable production coefficients are selected in descending order within the preset range of controllable production coefficient values, and then substituted into the intermittent pumping optimization model for re-solution; if there is still no solution, the peak-segment intermittent pumping production time is used as the optimized valley-segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, the optimized intermittent pumping regime is obtained based on the solution of the intermittent pumping optimization model.

[0009] If an initial solution exists, the well stoppage time is increased by a preset time step within the preset well stoppage time range. Based on the updated well stoppage time, the above process is repeated to obtain a new peak-segment intermittent pumping production time and to solve the problem until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, the optimized intermittent pumping system is determined.

[0010] In one or more optional embodiments of this application, the method further includes: obtaining the inter-sample optimization model based on preset control strategy constraints.

[0011]

[0012] Where N represents the number of intermittent pumping cycles within the peak segment, r1 = 1, 2, ..., N; M represents the number of intermittent pumping cycles within the valley segment, r2 = 1, 2, ..., M; t0 represents the start time of the r1th cycle within the peak segment or the start time of the r2th cycle within the valley segment; ta represents the time from pumping in the r1th cycle within the peak segment until the pump efficiency reaches the minimum stable pump efficiency, then ta-t0 represents the intermittent pumping production time within the peak segment; tb represents the time from pumping in the r2th cycle within the valley segment until the pump efficiency reaches the minimum pump efficiency in the low-efficiency, high-consumption zone of the pumping unit, then tb-t0 represents the intermittent pumping production time within the valley segment; Sp represents the cross-sectional area of ​​the pumping pump plunger; s represents the polished rod stroke of the pumping unit; n represents the number of pumping unit operating strokes; η represents the pump efficiency, which is the ratio of the effective pump stroke to the polished rod stroke; k is the production controllability coefficient, k = 0.85~1.0; η t The minimum stable pump efficiency represents the stable value of the pump efficiency when the target well is in continuous production; the left side of the intermittent pumping optimization model represents the sum of the peak production and valley production of the target well, and the right side of the intermittent pumping optimization model represents the controllable production volume when the target well is in continuous production.

[0013] The preset control strategy constraints are as follows:

[0014] The shutdown time is the same in the peak section and the valley section;

[0015] The peak-segment inter-pumping production time is the time during which the target well is shut down from the start-up time until the pump efficiency stabilizes during the peak segment.

[0016] The inter-well pumping production time in the valley-level section is the time from the start-up time of the target well in the valley-level section until it enters the low-efficiency, high-consumption zone and then shuts down.

[0017] In one or more optional embodiments of this application, before solving for the inter-valley pumping production time based on the preset inter-valley pumping optimization model, the method further includes:

[0018] The intermediate sampling optimization model is processed to obtain a simplified intermediate sampling optimization model:

[0019] N×(ta-t0)×(η0+η t ) / 2+M×(tb-t0)×(η0+2η t ) / 3≥k×1440×η t ;

[0020] Where N represents the number of pumping cycles in the peak section, N=a×60 / [(ta-t0)+ts], ts represents the well shutdown time, a represents the peak section duration, M represents the number of pumping cycles in the valley section, M=(24-a)×60 / [(tb-t0)+ts], and η0 represents the pumping efficiency at the start time.

[0021] In one or more optional embodiments of this application, the step of solving for the intermittent pumping production time in the valley-level section based on the peak period duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the intermittent pumping production time in the peak period using an intermittent pumping optimization model includes:

[0022] Based on the peak segment duration, the initial well shutdown duration, and the inter-peak segment pumping production duration, determine the initial peak segment pumping cycle number and the initial valley-level segment pumping cycle number.

[0023] Based on the initial peak-segment pumping cycle number, the initial valley-smooth-segment pumping cycle number, the pumping efficiency at startup, and the minimum stable pumping efficiency, the production time of intermittent pumping in the valley-smooth-segment is solved using the simplified intermittent pumping optimization model.

[0024] In one or more optional embodiments of this application, the method further includes:

[0025] The simplified intermittent pumping optimization model is transformed to obtain the equation regarding the intermittent pumping production time in the valley-flattening section:

[0026] in,

[0027]

[0028] In one or more optional embodiments of this application, if there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model for re-solution; if there is still no solution, the peak-segment intermittent pumping production time is used as the optimized valley-segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, the optimized intermittent pumping regime is obtained based on the solution of the intermittent pumping optimization model, including:

[0029] If there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model to solve the problem again.

[0030] If the intermittent pumping optimization model still has no solution under the condition that the production controllability coefficient is minimized, then the peak segment intermittent pumping production time is taken as the optimized valley segment intermittent pumping production time, the initial shutdown time is taken as the optimized shutdown time, and the peak segment intermittent pumping production time is taken as the optimized peak segment intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0031] If the intermittent pumping optimization model has a solution under the condition of a controllable production coefficient selected in sequence, then the solution of the intermittent pumping optimization model is used as the optimized intermittent pumping production time in the valley-level section, the initial well shutdown time is used as the optimized well shutdown time, and the intermittent pumping production time in the peak section is used as the optimized intermittent pumping production time in the peak section, thus obtaining the optimized intermittent pumping system.

[0032] In one or more optional embodiments of this application, the process of increasing the well stoppage time within a preset time step within a preset well stoppage time range if an initial solution exists, obtaining and re-executing the above-mentioned process of obtaining a new peak-segment intermittent pumping production time based on the updated well stoppage time, and solving the intermittent pumping optimization model until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time, and determining the optimized intermittent pumping system based on the solution of the previous intermittent pumping optimization model that had no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, includes:

[0033] If there is an initial solution, the well stop time is increased by a preset time step within the preset well stop time range. The process of obtaining a new peak segment inter-pumping production time and solving the inter-pumping optimization model based on the updated peak segment inter-pumping production time is repeated until there is no solution or the well stop time reaches the upper limit of the well stop time.

[0034] If the intermittent pumping optimization model has no solution under the conditions of an updated well stoppage duration selected in sequence and a production controllability coefficient selected within the range of preset production controllability coefficient values, then the solution of the previous intermittent pumping optimization model with no solution is taken as the optimized valley-level intermittent pumping production duration, and the updated well stoppage duration and the updated peak-level intermittent pumping production duration when the previous intermittent pumping optimization model with no solution are taken as the optimized well stoppage duration and the optimized peak-level intermittent pumping production duration, thus obtaining the optimized intermittent pumping system;

[0035] If the updated well stoppage time reaches the upper limit of the well stoppage time range, and the intermittent pumping optimization model still has a solution, then the current solution of the intermittent pumping optimization model is used as the optimized valley-level intermittent pumping production time, the upper limit of the well stoppage time is used as the optimized well stoppage time, and the updated peak-level intermittent pumping production time determined according to the upper limit of the well stoppage time is used as the optimized peak-level intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0036] Secondly, embodiments of the present invention provide an intelligent intermittent pumping control device for oil pumping units operating under peak-valley-flat electricity pricing, comprising:

[0037] The first calculation module is used to collect the dynamometer card of the target well during the peak period of continuous pumping within a preset time length, and calculate the minimum stable pump efficiency based on the collected dynamometer card.

[0038] The second calculation module is used to obtain the pumping efficiency at the start time when pumping is started after the initial shutdown time of the target well, collect the dynamometer diagram and calculate the pumping efficiency according to the preset time interval, record the time when pumping is started until the pumping efficiency reaches the minimum stable pumping efficiency, and calculate the peak-segment pumping production time.

[0039] The model solving module is used to solve the inter-valley pumping production time based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the inter-valley pumping production time during the peak segment, using an inter-valley pumping optimization model.

[0040] The first intermittent pumping optimization module is used to select controllable production coefficients in descending order within a preset range of controllable production coefficients when the intermittent pumping optimization model has no initial solution, and then substitute them into the intermittent pumping optimization model to solve it again; if there is still no solution, the peak segment intermittent pumping production time is used as the optimized valley segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, the optimized intermittent pumping regime is obtained according to the solution of the intermittent pumping optimization model.

[0041] The second intermittent pumping optimization module is used to, when the intermittent pumping optimization model has an initial solution, increase the well stoppage time within a preset well stoppage time range according to a preset time step, obtain and, based on the updated well stoppage time, re-execute the above process to obtain a new peak segment intermittent pumping production time and perform the solution, until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, determine the optimized intermittent pumping system.

[0042] Thirdly, embodiments of the present invention provide a computer-readable storage medium having a computer program / instruction stored thereon, which, when executed by a processor, implements the pumping control method for peak-valley-flat electricity pricing as described in the first aspect above.

[0043] Fourthly, embodiments of the present invention provide a computer program product, including a computer program / instruction, which, when executed by a processor, implements the pumping control method for peak-valley-flat electricity pricing as described in the first aspect above.

[0044] Fifthly, embodiments of the present invention provide a computer device, including a memory, a processor, and a computer program stored in the memory. When the processor executes the computer program, it implements the pumping control method for peak-valley-flat electricity pricing as described in the first aspect above.

[0045] The beneficial effects of the above-described technical solutions provided in the embodiments of the present invention include at least the following:

[0046] The intermittent pumping control method for oil pumping units under peak-valley-flat electricity pricing provided in this invention obtains the minimum stable pump efficiency through continuous pumping of the target well during peak periods. Based on the minimum stable pump efficiency, the intermittent pumping production time during peak periods is calculated. An intermittent pumping production time during valley periods is solved using an intermittent pumping optimization model. Depending on whether the intermittent pumping optimization model has a solution, the optimized intermittent pumping regime is determined under different scenarios with and without a solution. This allows for the use of different intermittent pumping regimes during peak and valley periods of industrial electricity pricing, rationally matching the peak-valley-flat electricity pricing system for industrial electricity consumption. This method can reduce intermittent pumping production time during peak periods, stopping the well before reaching the minimum stable pump efficiency, and fully utilizing the high-efficiency, low-consumption zone for production. Therefore, the pumped fluid is primarily the fluid recovered in the wellbore after well shutdown, which can mitigate the problem of high energy consumption due to high electricity prices and inefficient production during peak periods. In the valley-level section, the advantage of low electricity prices can be leveraged to optimize the intermittent pumping production time to maintain stable fluid production based on this intermittent pumping optimization model. This allows for appropriately extending the intermittent pumping production time to keep fluid production under control, and stopping the well when the controllable production time ends, avoiding excessive production in inefficient, high-consumption areas that wastes electricity and exacerbates equipment wear. Compared with conventional intelligent intermittent pumping methods, this approach offers significant cost reduction potential under stable fluid production conditions. It not only reduces daily power consumption and electricity costs, but also maximizes energy savings under controllable fluid production, achieving deep cost reduction and meeting the needs of refined production management. Moreover, the intermittent pumping control process requires no human intervention, improving the automation level of intermittent pumping control and demonstrating good field application results.

[0047] Other features and advantages of the invention will be set forth in the following description, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description and the accompanying drawings.

[0048] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0049] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0050] Figure 1 This is a flowchart illustrating the method for controlling inter-unit pumping under peak-valley flat electricity pricing provided in an embodiment of the present invention.

[0051] Figure 2 A schematic diagram illustrating the peak-valley-flat change in electricity prices within a day, provided as an embodiment of the present invention;

[0052] Figure 3 This is a schematic diagram of the dynamometer data for a pumping unit well.

[0053] Figure 4 A schematic diagram showing the pump efficiency variation of an intermittent pumping well in a day over n intermittent pumping production cycles using existing technology.

[0054] Figure 5 A schematic diagram of pump efficiency changes at the time of data acquisition for one intermittent pumping production cycle during peak and valley periods;

[0055] Figure 6 This is a schematic diagram of the change process of the dynamometer card collected during the pumping production of the target well in the valley section;

[0056] Figure 7 A schematic diagram of energy consumption changes at the time of data acquisition for an intermittent pumping production cycle during peak and valley periods.

[0057] Figure 8 This is a chart showing the daily electricity consumption of the Ning×× well pumping unit under different production methods;

[0058] Figure 9 This is a schematic diagram of an inter-pumping control device for peak-valley-flat electricity pricing provided in an embodiment of the present invention. Detailed Implementation

[0059] Exemplary embodiments of the present disclosure will now be described in more detail 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 implemented in various forms and should not be limited to 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.

[0060] The inventors discovered that, to achieve deep energy savings, pumping units should reduce operation or even shut down during peak electricity price periods and extend operation during off-peak periods, but effective optimization control methods are lacking. Currently, most oilfields rely on experience to determine intermittent pumping based on peak, off-peak, and off-peak electricity prices, or manually set the start-up and shutdown times for intermittent pumping, or even directly adopt a mode of shutting down wells during peak periods and continuing production during off-peak periods. These modes lack theoretical support for optimization. In particular, in order to avoid the excessive shutdown time caused by directly shutting down wells during peak electricity price periods, which leads to reduced oil production, continuous production during off-peak periods also results in the well's dynamic fluid level being lowered and then operating in an inefficient and high-consumption mode for a long time, not much different from the conventional continuous 24-hour inefficient production, and thus failing to achieve efficient production.

[0061] While some methods for optimizing peak-valley-flat power consumption have been proposed, their effectiveness has fallen short of the inventor's expectations. For example, one method determines the need for intermittent pumping based on well fluid volume. If intermittent pumping is required, the duration is calculated using the dynamometer card, the current operating time is identified, and a shutdown plan is formulated based on the current time and the corresponding peak-valley-flat power consumption periods for the day, prioritizing shutdown according to peak and valley times, with the lowest possible power cost as the control objective. This technology controls start-up and shutdown according to a set priority, aiming for the lowest possible power cost. However, this can easily lead to excessively long shutdown times. Although the energy consumption reduction effect is significant, the shorter production time can result in reduced production compared to continuous pumping, making it difficult to maintain controllable fluid production.

[0062] For example, by grouping different product liquids corresponding to pump diameter, pump depth, stroke, and stroke count, and applying different production times for different electricity price stages, with the production time for each stage set manually, the daily power consumption cost under each group's pumping regime is calculated. The combination of production parameters that minimizes power consumption while meeting the set output is then selected as the optimal design result. However, since the pumping regime and target output for each group are set manually, this method relies on human experience, lacks autonomous automatic optimization, and makes it difficult to maintain controllable output.

[0063] In summary, while the large-scale application of intelligent intermittent pumping technology has solved the problem of supply and drainage coordination and achieved energy conservation and efficiency improvement for the numerous low-yield and inefficient pumping wells currently in operation, the peak-valley-flat electricity pricing system in industrial electricity use means that the peak-period electricity price is approximately twice that of the off-peak period. Conventional intelligent intermittent pumping control strategies do not reasonably match the peak-valley-flat electricity pricing system of industrial electricity use and have not achieved maximum energy savings under stable production. Therefore, there is an urgent need to develop intelligent intermittent pumping technology based on peak-valley-flat electricity pricing to optimize the intermittent pumping system during peak and off-peak periods, so as to minimize costs to the greatest extent while maintaining controllable production of oil wells. This has become a pressing technical problem to be solved. Based on this, the inventors have further developed this invention, providing a method, device, and equipment for controlling intermittent pumping of pumping units based on peak-valley-flat electricity pricing, achieving significant cost reduction and meeting the needs of refined production management.

[0064] Example 1

[0065] Embodiment 1 of the present invention provides a method for controlling inter-pumping of oil pumping units under peak-valley flat electricity pricing, referring to... Figure 1 As shown, the method may include the following steps S101-S105:

[0066] S101: Collect dynamometer diagrams of the target well during continuous pumping within a preset time period during the peak period, and calculate the minimum stable pump efficiency based on the collected dynamometer diagrams;

[0067] S102: When pumping is started after the initial shutdown time of the target well, the pumping efficiency at the start time is obtained, the dynamometer is collected and the pumping efficiency is calculated according to the preset time interval, the pumping is recorded until the pumping efficiency reaches the minimum stable pumping efficiency, and the peak-segment pumping production time is calculated.

[0068] S103: Based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the peak segment inter-pumping production duration, solve for the valley-level inter-pumping production duration using the inter-pumping optimization model, and determine whether the inter-pumping optimization model has a solution; if there is no initial solution, proceed to step S104; if there is an initial solution, proceed to step S105.

[0069] S104: Within the preset range of controllable production coefficient values, select controllable production coefficients in descending order and substitute them into the intermittent pumping optimization model for re-solution; if there is still no solution, use the peak-segment intermittent pumping production time as the optimized valley-segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, obtain the optimized intermittent pumping regime based on the solution of the intermittent pumping optimization model.

[0070] S105: Within the preset shutdown time range, increase the shutdown time according to the preset time step, obtain and based on the updated shutdown time, re-execute the above steps S102 and S103 to obtain the new peak intermittent pumping production time, and perform the solution process until there is no solution or the shutdown time reaches the shutdown time limit. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the shutdown time limit condition, determine the optimized intermittent pumping system.

[0071] The intermittent pumping control method for oil pumping units under peak-valley-flat electricity pricing provided in this invention obtains the minimum stable pump efficiency through continuous pumping of the target well during peak periods. Based on the minimum stable pump efficiency, the intermittent pumping production time during peak periods is calculated. An intermittent pumping production time during valley periods is solved using an intermittent pumping optimization model. Depending on whether the intermittent pumping optimization model has a solution, the optimized intermittent pumping regime is determined under different scenarios with and without a solution. This allows for the use of different intermittent pumping regimes during peak and valley periods of industrial electricity pricing, rationally matching the peak-valley-flat electricity pricing system for industrial electricity consumption. This method can reduce intermittent pumping production time during peak periods, stopping the well before reaching the minimum stable pump efficiency, and fully utilizing the high-efficiency, low-consumption zone for production. Therefore, the pumped fluid is primarily the fluid recovered in the wellbore after well shutdown, which can mitigate the problem of high energy consumption due to high electricity prices and inefficient production during peak periods. In the valley-level section, the advantage of low electricity prices can be leveraged to optimize the intermittent pumping production time to maintain stable fluid production based on this intermittent pumping optimization model. This allows for appropriately extending the intermittent pumping production time to keep fluid production under control, and stopping the well when the controllable production time ends, avoiding excessive production in inefficient, high-consumption areas that wastes electricity and exacerbates equipment wear. Compared with conventional intelligent intermittent pumping methods, this approach offers significant cost reduction potential under stable fluid production conditions. It not only reduces daily power consumption and electricity costs, but also maximizes energy savings under controllable fluid production, achieving deep cost reduction and meeting the needs of refined production management. Moreover, the intermittent pumping control process requires no human intervention, improving the automation level of intermittent pumping control and demonstrating good field application results.

[0072] In an optional embodiment, the preset time length in step S101 can be selected according to actual conditions, but it should be noted that the preset time length must be shorter than the peak duration of industrial electricity consumption. (Refer to...) Figure 2 As shown, assuming the peak period for industrial electricity consumption is 8 hours from 4 PM to midnight and the off-peak period is 16 hours from midnight to 4 PM, the preset time length can be selected within 8 hours. As long as the target well can reach a stable pump efficiency during continuous production after continuous pumping for this preset time length, the minimum effective pump efficiency can be obtained. For example, the preset time length can be set to 4 hours. In this case, during step S101, the target well can pump continuously for 4 hours, then stop. During the pumping process, a dynamometer is used to collect a dynamometer chart, and the minimum stable pump efficiency η is calculated based on the collected dynamometer chart. t .

[0073] In this embodiment of the invention, in step S101 above, when collecting the dynamometer diagram using the pumping unit dynamometer, the dynamometer can collect the diagram at preset time intervals. These time intervals can be set according to actual conditions, for example, 3 to 6 minutes. (Refer to...) Figure 3The diagram shown is a schematic representation of a dynamometer card collected from a pumping unit well. In this embodiment of the invention, the process of calculating pump efficiency based on the collected dynamometer card can be described in detail in the prior art, and is not specifically limited here.

[0074] In an optional embodiment, during the intelligent intermittent pumping control process of the target well, the shutdown time range of the target well can be preset, such as 40 min to 120 min. Therefore, the initial shutdown time in step S102 can be set to 40 min. When executing step S102, after the target well has reached the initial shutdown time, the pumping unit starts pumping. The dynamometer at the start of pumping can be immediately collected. Based on the dynamometer at the start of pumping, the pumping efficiency is calculated. Furthermore, during the pumping process, the dynamometer is collected and the pumping efficiency is calculated at each preset time interval. Pumping is stopped when the pumping efficiency approaches the minimum stable pumping efficiency ηt. The time when pumping reaches the minimum stable pumping efficiency is recorded. The start of pumping is then subtracted from the time when the minimum stable pumping efficiency is reached to obtain the peak intermittent pumping production time.

[0075] In this embodiment of the invention, the inventors obtained the inter-sample optimization model in step S103 above through the following method:

[0076] When a pumping unit well is producing continuously throughout the day, the production calculation formula based on the dynamometer diagram of the pumping unit well is shown in Formula 1:

[0077] Q=1440×Sp×s×n×η Formula 1;

[0078] Where 1440 represents the number of minutes of production per day (min); Sp represents the cross-sectional area of ​​the pump plunger (m2); s represents the stroke of the polished rod of the pumping unit (m); n represents the number of pumping unit strokes (min-1); and η represents the pump efficiency, which is the ratio of the effective pump stroke to the polished rod stroke, calculated from the indicator diagram.

[0079] As can be seen from the above production calculation formula, the production calculated for each dynamometer chart is the output for a total production time of 1440 minutes per day. In field applications, the production is calculated by averaging the output of each dynamometer chart collected every hour. This is more effective for wells with stable production and minimal fluctuations in the shape of the dynamometer chart.

[0080] Reference Figure 4 As shown, for wells pumped between pumping units, assuming fixed production and shutdown periods, the total production time for n pumping cycles within a day will definitely be less than 1440 minutes. Pump efficiency η is positively correlated with submersion. After a well pumped between pumping units shuts down, the dynamic fluid level rises, the submersion increases, and pump efficiency η is high upon restarting. As production time increases, pump efficiency η gradually decreases, eventually reaching a stable pump efficiency η for continuous 24-hour pumping under supply-production balance. tThis leads to a low-efficiency, high-consumption zone. Therefore, the common practice for pumping wells between pumping units is to calculate the production based on the dynamometer data collected during one pumping cycle per day. This yields the production volume for one pumping cycle, which is then summed according to the number of pumping cycles per day to obtain the daily production volume. The formula for calculating the production of pumping wells between pumping units is shown in Formula 2:

[0081]

[0082] Where N is the number of well start-stop cycles, and k = 1, 2, ..., N.

[0083] Due to frequent well starts and stops between pumping units, the dynamometer charts fluctuate greatly. To improve the accuracy of production calculation, the usual method of collecting one dynamometer chart per hour is not suitable for pumping between pumping units. Therefore, a method is adopted where dynamometer charts are collected more frequently during well start-up production, and the pumping unit dynamometer is dormant and no data is collected during well shutdown. In each well start-up production cycle, the dynamometer charts collected more frequently and the collection time are recorded by a Remote Terminal Unit (RTU). The frequency is increased to one dynamometer chart every 3-6 minutes. Production is calculated using time integration for each dynamometer chart. The first integration calculation starts from the well start-up time to the time when the first dynamometer chart is collected, the second integration calculation starts from the time when the first dynamometer chart is collected to the time when the second dynamometer chart is collected, and so on. The final integration calculation in the well start-up cycle is based on the integration from the time when the last dynamometer chart is collected to the time when the well is shut down. This calculation gives the production value for one intermittent pumping production cycle. Then, the production values ​​for each intermittent pumping production cycle within a day are summed. Once the pump efficiency η of the pumping unit between wells stabilizes, the production status gradually stabilizes. In other words, after the same well shutdown time, each cycle after restarting pumping and stabilizing the production status is similar. Therefore, we can calculate the production volume of one cycle, and then calculate the number of intermittent pumping production cycles per day based on the intermittent pumping production cycle length (starting time plus shutdown time), and then obtain the calculated production of the pumping unit between wells per day. This can avoid the problem of rapid battery wear and reduced service life caused by long-term, high-frequency acquisition of dynamometer charts.

[0084] This method, on the one hand, increases the number of dynamometer charts collected by encrypting the data, ensuring that dynamometer charts at different production stages during the well start-up time of the pumping unit can be collected to the greatest extent. It collects the full state of a pumping production cycle, expanding the coverage and broadly reflecting the production status of the oil well. On the other hand, this integration method uses minutes as the integration unit, and the start-up and shutdown times as well as the collection time of each dynamometer chart are all recorded in detail in the RTU. Compared with the previous method of collecting and calculating production time in hours, this method can improve accuracy.

[0085] The purpose of calculating the production of intermittent pumping wells is to optimize the intermittent pumping system while maintaining a production level that is essentially consistent with the production of the well during 24-hour continuous production. Otherwise, intermittent pumping would cause a drop in production, making it difficult for field and technical personnel to widely accept the technology, thus hindering its widespread adoption. The objectives of intermittent pumping are twofold: first, to achieve energy savings through reduced well shutdown time; and second, to maintain controllable production, meaning that production should not decrease significantly after intermittent pumping, achieved through improved pump efficiency and optimized production duration after well shutdown. However, the conventional intermittent pumping technology mentioned above does not consider peak-valley-flat electricity pricing. During peak and off-peak periods of industrial electricity consumption, the start-up and shutdown times are random, preventing the full exploitation of the cost-reduction potential of intermittent pumping wells. Therefore, it is necessary to develop an intermittent pumping system optimization model that considers peak-valley-flat electricity pricing.

[0086] After considering peak-valley-flat electricity pricing, the peak-segment price is approximately twice the valley-flat-segment price. Given that peak and valley-flat-segment electricity consumption in industrial settings are concentrated in their respective time periods, intelligent inter-valley-flat-segment electricity extraction can be optimized in two main segments. To facilitate optimization and improve efficiency, it is necessary to consider incorporating the corresponding time period information of the peak-valley-flat-segment price and pre-setting extraction control strategy constraints. In this embodiment, the inter-valley-flat-segment extraction control strategy constraints are as follows:

[0087] (1) The well stoppage time ts is consistent between the peak section and the valley section pumping system;

[0088] (2) Peak-segment pumping production time ta is the time from well start-up to when the pumping efficiency η stabilizes between pumping units. t The length of time before well shutdown is determined to fully utilize the high-efficiency zone for production;

[0089] (3) The inter-pumping production time tb in the valley section is the time from the start of the pumping well to the start of the high-consumption zone and then the well is shut down. The specific time is determined by the inter-pumping optimization model.

[0090] Based on the above control strategy conditions, the intermittent evacuation optimization model is obtained as follows:

[0091]

[0092] Where N represents the number of intermittent pumping cycles within the peak segment, r1 = 1, 2, ..., N; M represents the number of intermittent pumping cycles within the valley segment, r2 = 1, 2, ..., M; t0 represents the start time of the r1th cycle within the peak segment or the start time of the r2th cycle within the valley segment; ta represents the time from pumping in the r1th cycle within the peak segment until the pump efficiency reaches the minimum stable pump efficiency, then ta-t0 represents the intermittent pumping production time within the peak segment; tb represents the time from pumping in the r2th cycle within the valley segment until the pump efficiency reaches the minimum pump efficiency in the low-efficiency, high-consumption zone of the pumping unit, then tb-t0 represents the intermittent pumping production time within the valley segment; Sp represents the cross-sectional area of ​​the pumping pump plunger; s represents the polished rod stroke of the pumping unit; n represents the number of pumping unit operating strokes; η represents the pump efficiency, which is the ratio of the effective pump stroke to the polished rod stroke; k is the production controllability coefficient, k = 0.85~1.0; η t The minimum stable pump efficiency represents the stable value of the pump efficiency when the target well is in continuous production. The left side of the intermittent pumping optimization model represents the sum of the peak production and valley production of the target well, while the right side of the intermittent pumping optimization model represents the controllable production volume when the target well is in continuous production.

[0093] In this embodiment of the invention, t0 is the start time of pumping, that is, the time when the intermittent pumping system begins to optimize, and ta is the time when the pump efficiency reaches the minimum stable pump efficiency, that is, the time when the pump efficiency change tends to level off during peak intermittent pumping. For example, assuming the peak intermittent pumping production duration ta-t0 is 30 minutes, and the start time ta of the previous intermittent pumping is 14:28, then the time ta when the pump efficiency reaches the minimum stable pump efficiency is 14:58. Assuming the well shutdown time ts of intermittent pumping is 40 minutes, then the start time ta of the next intermittent pumping becomes 15:38, and the time ta when the pump efficiency reaches the minimum stable pump efficiency becomes 16:08.

[0094] In this embodiment of the invention, the physical meaning of the intermittent pumping optimization model is that the sum of the cumulative fluid production during the daily peak period and the cumulative fluid production during the valley period of the target well is not less than the controllable fluid production during continuous daily production. The optimal production time during the valley period is determined through the intermittent pumping optimization model. Specifically, after the target well continues production from the start of pumping at time t0 to time tb in the valley period, it is not only inefficient and energy-intensive, but also difficult to increase the fluid production.

[0095] In one specific embodiment, for ease of calculation, both sides of the above intermittent evacuation optimization model are divided by the plunger cross-sectional area Sp, stroke s, and number of strokes n, then the intermittent evacuation optimization model becomes:

[0096]

[0097] Furthermore, considering that the pump efficiency change after the intermittent pumping well starts production is approximately linear, in order to facilitate efficient optimization and solve the intermittent pumping production time in the valley leveling section, the inventors regarded the pump efficiency change process as the change from the initial pumping pump efficiency η0 at the start of pumping to the lowest stable pump efficiency η. t If the line is straight, then the simplified indirect simplification optimization model is:

[0098] N×(ta-t0)×(η0+η t ) / 2+M×(tb-t0)×(η0+2η t ) / 3≥k×1440×η t .

[0099] In this embodiment of the invention, it is known that the number of intermittent pumping cycles per day = total day duration / (intermittent pumping start duration + intermittent pumping shutdown duration). Therefore, the number of pumping cycles during the peak period N = a × 60 / [(ta - t0) + ts], where ts represents the shutdown duration and a represents the peak period duration. The number of pumping cycles during the valley period M = (24 - a) × 60 / [(tb - t0) + ts].

[0100] In a specific embodiment, based on the simplified intermittent pumping optimization model described above, the step S103 described above, which calculates the intermittent pumping production time in the valley-level section based on the peak period duration, the pumping start-up efficiency, the minimum stable pumping efficiency, the initial well shutdown duration, and the peak period intermittent pumping production time, may specifically include:

[0101] Based on the peak segment duration, the initial well shutdown duration, and the inter-peak segment pumping production duration, determine the initial peak segment pumping cycle number and the initial valley-level segment pumping cycle number.

[0102] Based on the initial peak-segment pumping cycle number, the initial valley-smooth-segment pumping cycle number, the pumping efficiency at startup, and the minimum stable pumping efficiency, the production time of intermittent pumping in the valley-smooth-segment is solved using the simplified intermittent pumping optimization model.

[0103] Furthermore, the inventors transformed the simplified intermittent pumping optimization model into a linear equation in one variable concerning the intermittent pumping production time tb-t0 in the valley-leveling section, i.e.

[0104] in,

[0105]

[0106] For example, assuming that the peak period 'a' of industrial electricity consumption in a day lasts for 8 hours, substituting it into the above equation yields:

[0107]

[0108] In this embodiment of the invention, based on the above-mentioned linear equation regarding the inter-valley pumping production time tb-t0, the above step S103, which involves solving for the inter-valley pumping production time based on the inter-valley pumping optimization model according to the peak period duration, the pumping start-up efficiency, the minimum stable pumping efficiency, the initial well shutdown duration, and the peak period inter-valley pumping production time, may specifically include:

[0109] Based on the peak duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the inter-peak pumping production duration, the inter-valley pumping production duration is solved using a linear equation in one variable concerning the inter-valley pumping production duration.

[0110] In one specific embodiment, if there is no initial solution as described in step S104 above, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model for re-solution; if there is still no solution, the peak-segment intermittent pumping production time is used as the optimized valley-segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, the optimized intermittent pumping regime is obtained based on the solution of the intermittent pumping optimization model, specifically including:

[0111] If there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model to solve the problem again.

[0112] If the intermittent pumping optimization model still has no solution under the condition that the production controllability coefficient is minimized, then the peak segment intermittent pumping production time is taken as the optimized valley segment intermittent pumping production time, the initial shutdown time is taken as the optimized shutdown time, and the peak segment intermittent pumping production time is taken as the optimized peak segment intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0113] If the intermittent pumping optimization model has a solution under the condition of a controllable production coefficient selected in sequence, then the solution of the intermittent pumping optimization model is used as the optimized intermittent pumping production time in the valley-level section, the initial well shutdown time is used as the optimized well shutdown time, and the intermittent pumping production time in the peak section is used as the optimized intermittent pumping production time in the peak section, thus obtaining the optimized intermittent pumping system.

[0114] When selecting the controllable coefficient of production in descending order within the preset range of controllable coefficient values, the initial controllable coefficient can be freely selected according to actual needs. For example, the initial controllable coefficient can be 0.95, and then the next smaller controllable coefficient can be selected according to the set difference, such as 0.01. If the indirect extraction optimization model still has no solution under the initial controllable coefficient, the next controllable coefficient of production selected in sequence is 0.94, and so on, selecting the controllable coefficient of production in descending order within the preset range of controllable coefficient values.

[0115] In this embodiment of the invention, when solving the initial solution of the intermittent pumping optimization model for the first time, the production controllability coefficient is defaulted to 1.0. If there is no initial solution, it indicates that the production of the target well is low, making it difficult to maintain production during intermittent pumping. Therefore, the inventors propose selecting the production controllability coefficient within a reasonable range, ensuring that the production of the target well does not decrease significantly during intermittent pumping. Thus, the minimum value of the production controllability coefficient can be 0.85, indicating that the production during intermittent pumping can reach 85% of that during continuous pumping, in order to maximize the solution of the intermittent pumping optimization model. If the intermittent pumping optimization model still has no solution even when the production controllability coefficient reaches its minimum value, then the peak-segment intermittent pumping production time is used as the optimized valley-level intermittent pumping production time, the initial shutdown time is used as the optimized shutdown time, and the peak-segment intermittent pumping production time is used as the optimized peak-segment intermittent pumping production time, thus obtaining the optimized intermittent pumping regime.

[0116] If the intermittent pumping optimization model has a solution under the condition of a controllable production coefficient selected sequentially, it means that the production of the target well has decreased somewhat after taking the controllable production coefficient. At this time, the model solution is directly adopted to minimize the decrease in oil well production. If the well shutdown time is increased for optimization, the production will decrease further. Each increase in the well shutdown time will cause the production to decrease slightly in the next round because the model approximates the pump efficiency change curve as a straight line, while the actual situation is a curve. Approximating it as a straight line actually overestimates the pump efficiency, and the calculated production value is slightly larger than the actual value. Therefore, in order to avoid excessive production decrease caused by intermittent pumping optimization, there is no need to continue optimization after taking the controllable production coefficient. For example, if the model has a solution when the production controllability coefficient k = 0.9, then the solution of the intermittent pumping optimization model when the production controllability coefficient k = 0.9 is taken as the optimized intermittent pumping production time in the valley-level section, the initial well shutdown time is taken as the optimized well shutdown time, and the peak section intermittent pumping production time is taken as the optimized peak section intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0117] In one specific embodiment, the process described in step S105 above, where an initial solution exists, involves increasing the well stoppage time within a preset time step within a preset well stoppage time range, obtaining and re-executing the process of obtaining a new peak-segment intermittent pumping production time based on the updated well stoppage time, and solving the intermittent pumping optimization model, until no solution is found or the well stoppage time reaches the upper limit. Based on the solution of the previous intermittent pumping optimization model that yielded no solution or the solution of the intermittent pumping optimization model under the upper limit condition of the well stoppage time, the optimized intermittent pumping regime is determined, which may specifically include:

[0118] If there is an initial solution, the well stoppage time is increased by a preset time step within the preset well stoppage time range. Based on the updated well stoppage time, steps S102 and S103 are re-executed to obtain a new peak-segment inter-pumping production time. The inter-pumping optimization model is then solved based on the updated peak-segment inter-pumping production time until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time.

[0119] If the intermittent pumping optimization model has no solution under the conditions of an updated well stoppage duration selected in sequence and a production controllability coefficient selected within the range of preset production controllability coefficient values, then the solution of the previous intermittent pumping optimization model with no solution is taken as the optimized valley-level intermittent pumping production duration, and the updated well stoppage duration and the updated peak-level intermittent pumping production duration when the previous intermittent pumping optimization model with no solution are taken as the optimized well stoppage duration and the optimized peak-level intermittent pumping production duration, thus obtaining the optimized intermittent pumping system;

[0120] If the updated well stoppage time reaches the upper limit of the well stoppage time range, and the intermittent pumping optimization model still has a solution, then the current solution of the intermittent pumping optimization model is used as the optimized valley-level intermittent pumping production time, the upper limit of the well stoppage time is used as the optimized well stoppage time, and the updated peak-level intermittent pumping production time determined according to the upper limit of the well stoppage time is used as the optimized peak-level intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0121] In this embodiment of the invention, the preset well stoppage duration range can be set according to the actual situation, and the preset time step when increasing the well stoppage duration can also be set according to the actual situation.

[0122] For example, if the preset well stoppage time range is 40 min to 120 min and the preset time step is 10 min, then the initial well stoppage time is 40 min. If the intermittent pumping optimization model has an initial solution, then the well stoppage time is increased by one step, resulting in an updated well stoppage time of 50 min. Step S102 is then executed again to obtain the updated peak-segment intermittent pumping production time. Based on the peak-segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the updated well stoppage time, and the updated peak-segment intermittent pumping production time, step S103 is executed again. If the intermittent pumping optimization model still has a solution, then the well stoppage time is increased by one step, resulting in an updated well stoppage time of 600 min. Step S102 is then executed again to obtain the updated peak-segment intermittent pumping production time. Then, based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the updated well stoppage duration, and the updated peak segment intermittent pumping production duration, step S103 is repeated. If the intermittent pumping optimization model still has a solution, the well stoppage duration is increased, and steps S102 and S103 are repeated until the updated well stoppage duration reaches the upper limit of 120 minutes. At the upper limit of 120 minutes, the current solution of the intermittent pumping optimization model is used as the optimized valley-level intermittent pumping production duration, the upper limit of the well stoppage duration is used as the optimized well stoppage duration, and the updated peak segment intermittent pumping production duration determined according to the upper limit of the well stoppage duration is used as the optimized peak segment intermittent pumping production duration, thus obtaining the optimized intermittent pumping system.

[0123] If, during the iterative execution of steps S102 and S103 according to a preset time step, the intermittent pumping optimization model has no solution, then the solution of the previous intermittent pumping optimization model with no solution is taken as the optimized valley-level intermittent pumping production time. For example, assuming a well stoppage time of 70 minutes, if the intermittent pumping optimization model has no solution, then the solution of the intermittent pumping optimization model with a well stoppage time of 60 minutes is taken as the optimized valley-level intermittent pumping production time, and the well stoppage time of 60 minutes is taken as the optimized well stoppage time. The updated peak-level intermittent pumping production time obtained by executing step S102 with a well stoppage time of 60 minutes is taken as the optimized peak-level intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

[0124] In this embodiment of the invention, during the model optimization process, the well shutdown time is gradually extended to save energy. The existence of a solution in the intermittent pumping optimization model indicates that the model is valid. That is, under the condition of intermittent pumping production with the updated well shutdown time, the target well can still maintain controllable fluid production, indicating that there is still room for optimization in the intermittent pumping system. In other words, while ensuring stable fluid production, the well shutdown time can be increased. Increasing the well shutdown time means saving energy. The more energy-efficient the better under stable fluid production, the better. The well shutdown time needs to be increased to find if there is still a solution. If the intermittent pumping optimization model has no solution, it means that under the updated well shutdown time, the target well cannot meet the controllable fluid production requirement for intermittent pumping production. This indicates that the well shutdown time is too long, causing a reduction in production. The solution of the intermittent pumping optimization model under the previous well shutdown time is the optimal well shutdown time, which satisfies the intermittent pumping production time in the valley-flat section with controllable fluid production.

[0125] In this embodiment of the invention, after determining the intermittent pumping regime for the target well through optimization, production can be carried out according to the intermittent pumping regime. In actual production, a cycle for optimizing the intermittent pumping regime can be set, for example, 30 days. Then, after the target well has been producing according to the current intermittent pumping regime for 30 days, the intermittent pumping regime optimization process is executed again according to the aforementioned peak-valley-flat electricity price pumping unit intermittent pumping control method to obtain a new intermittent pumping regime. (Refer to...) Figure 5 As shown, for the optimized peak-segment pumping production time, the well is shut down after the pumping unit starts pumping until the pump efficiency stabilizes, i.e., when the minimum stable pump efficiency ηt is reached. For the valley-level pumping production time, the well is shut down after the pumping unit starts pumping until the pump efficiency stabilizes, i.e., when the minimum stable pump efficiency ηt is reached. t Afterwards, pumping is carried out for a period of time in the low-efficiency, high-consumption area while maintaining stable fluid production, before stopping the well. (Refer to...) Figure 6 The image shows the changes in the dynamometer card collected during the start-up of a target well in the valley level section under an intermittent pumping regime. Figure 6 Figures ①, ②, and ③ show the changes in the dynamometer diagrams after the well is started, representing the duration of the first round of inter-valley pumping production. Figure 6 Figures ④ to ⑧ show the changes in the dynamometer card after well start-up during the second round of inter-valley pumping production. As can be seen from the figures, after the pump efficiency stabilizes in the valley section, although the fluid production is low, there is still fluid production, and the production is stable. (Refer to...) Figure 7 As shown, within an intermittent pumping cycle, regardless of the intermittent pumping production time during the peak or valley periods, under the current intermittent pumping system, both the peak and valley periods exhibit the characteristics of high well efficiency and low energy consumption when pump efficiency is high, followed by decreased efficiency and increased energy consumption after pump efficiency stabilizes.

[0126] To provide a clearer and more complete explanation of the pumping unit intermittent pumping control method based on peak-valley-flat electricity pricing provided in this embodiment of the invention, the following example of the Ning×× well in a certain production unit of an oilfield is used to illustrate the application effect of this embodiment of the invention compared with the application effect of conventional methods.

[0127] Given that the pumping unit of the Ning×× well has a pump diameter of 32mm, a pump depth of 2302m, a stroke of 4m, a stroke frequency of 3.8min-1, and the dynamometer card acquisition has been upgraded to a high-density acquisition mode, under the all-day production mode, according to the above formula 1, the daily liquid production is 1.1 cubic meters, the daily power consumption is 150 kWh, and the daily electricity cost is 82 yuan;

[0128] The method was changed to a mode where wells were shut down directly during peak electricity price periods and pumped continuously (without stopping) during off-peak periods. According to the formula above, the daily production of liquid was 0.7 cubic meters, the daily electricity consumption was 82 kWh, and the daily electricity cost was 42 yuan.

[0129] The process was changed to a fixed well shutdown duration intermittent pumping mode. The intermittent pumping schedule was consistent throughout the day: 55 minutes of pumping production followed by 62 minutes of well shutdown. According to the formula above, the daily production was 1.0 cubic meters of liquid, the daily power consumption was 78 kWh, and the daily electricity cost was 40 yuan.

[0130] The pumping system is upgraded to the intelligent intermittent pumping control system for pumping units with peak-valley-flat electricity pricing according to the embodiments of the present invention. The intermittent pumping system is 40 minutes of production during peak hours and 60 minutes of well shutdown, 70 minutes of production during valley hours and 60 minutes of well shutdown. The calculated daily production is 1.0 cubic meters, the daily electricity consumption is 60 kWh, and the daily electricity cost is 29 yuan.

[0131] Compared to the full-day production method, the intermittent pumping system of this invention provides a relatively stable daily fluid production. Compared to the mode of directly shutting down wells during peak electricity price periods, the intermittent pumping system obtained using this invention significantly increases the daily fluid production, while maintaining the same production as the intermittent pumping mode with a fixed shutdown duration. (Refer to...) Figure 8 As shown, compared with the full-day production method, the intermittent pumping system of this invention can significantly reduce power consumption and daily electricity costs. Compared with the production method of directly shutting down the well during peak electricity price periods, the power consumption and daily electricity costs of the intermittent pumping system of this invention are basically the same. Compared with the intermittent pumping system with fixed well shutdown time, the daily power consumption is slightly lower, and the daily electricity costs are significantly reduced, achieving good field application results.

[0132] Example 2

[0133] Based on the same inventive concept, this invention also provides an intelligent intermittent pumping control device for oil pumping units operating under peak-valley flat-rate electricity pricing, as described above. Figure 9 As shown, the device includes:

[0134] The first calculation module 101 is used to collect the dynamometer diagram of the target well during continuous pumping within a preset time period during the peak period, and calculate the minimum stable pump efficiency based on the collected dynamometer diagram.

[0135] The second calculation module 102 is used to obtain the pumping efficiency at the start time when pumping is started after the initial shutdown time of the target well, collect the dynamometer diagram and calculate the pumping efficiency according to the preset time interval, record the time when pumping is started until the pumping efficiency reaches the minimum stable pumping efficiency, and calculate the peak-segment pumping production time.

[0136] The model solving module 103 is used to solve the inter-valley pumping production time based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the inter-valley pumping production time during the peak segment, using an inter-valley pumping optimization model.

[0137] The first intermittent pumping optimization module 104 is used to select the controllable production coefficient in descending order within the preset range of controllable production coefficient values ​​when the intermittent pumping optimization model has no initial solution, and then substitute them into the intermittent pumping optimization model to solve it again; if there is still no solution, the peak segment intermittent pumping production time is used as the optimized valley segment intermittent pumping production time to obtain the optimized intermittent pumping regime; if there is a solution, the optimized intermittent pumping regime is obtained according to the solution of the intermittent pumping optimization model.

[0138] The second intermittent pumping optimization module 105 is used to, when the intermittent pumping optimization model has an initial solution, increase the well stoppage time within a preset well stoppage time range according to a preset time step, obtain and, based on the updated well stoppage time, re-execute the above process to obtain a new peak segment intermittent pumping production time and perform the solution, until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, determine the optimized intermittent pumping system.

[0139] Example 3

[0140] Based on the same inventive concept, embodiments of the present invention also provide a computer-readable storage medium storing a computer program / instruction thereon, which, when executed by a processor, implements the pumping control method for peak-valley-flat electricity pricing as described in Embodiment 1 above.

[0141] Example 4

[0142] Based on the same inventive concept, this embodiment of the invention also provides a computer program product, including a computer program / instruction, which, when executed by a processor, implements the pumping control method for peak-valley-flat electricity pricing as described in Embodiment 1 above.

[0143] Example 5

[0144] Based on the same inventive concept, this embodiment of the invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory. When the processor executes the computer program, it implements the pumping control method for peak-valley-flat electricity pricing as described in Embodiment 1 above.

[0145] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage and optical storage) containing computer-usable program code.

[0146] This 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 block of the flowchart illustrations and / or block diagrams, as well as combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can 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, generate instructions for implementing the flowchart. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0147] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0148] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0149] Obviously, those skilled in the art can make various modifications and variations to this invention without departing from its spirit and scope. Therefore, if these modifications and variations fall within the scope of the claims of this invention and their equivalents, this invention also intends to include these modifications and variations.

Claims

1. A method for controlling inter-unit pumping in oil wells under peak-valley flat electricity pricing, characterized in that, include: During the peak period, dynamometer diagrams of the target well during continuous pumping within a preset time length are collected, and the minimum stable pump efficiency is calculated based on the collected dynamometer diagrams. When pumping is started after the initial shutdown time of the target well, the pumping efficiency at the start time is obtained, the dynamometer is collected and the pumping efficiency is calculated according to the preset time interval, the pumping time until the pumping efficiency reaches the minimum stable pumping efficiency is recorded, and the peak-segment pumping production time is calculated. Based on the peak duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the peak inter-pumping production duration, the valley-level inter-pumping production duration is solved using an inter-pumping optimization model. If there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model to solve the problem again. If there is still no solution, the peak-segment inter-sampling production time will be used as the optimized valley-segment inter-sampling production time to obtain the optimized inter-sampling system. If a solution exists, the optimized intermittent sampling regime is obtained based on the solution of the intermittent sampling optimization model. If an initial solution exists, the well stoppage time is increased by a preset time step within the preset well stoppage time range. Based on the updated well stoppage time, the process of obtaining a new peak-segment intermittent pumping production time and solving the problem is repeated until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, the optimized intermittent pumping system is determined.

2. The method according to claim 1, characterized in that, Also includes: Based on the preset control strategy constraints, the inter-sample optimization model is obtained: Where N represents the number of intermittent pumping cycles within the peak segment, r1 = 1, 2, ..., N; M represents the number of intermittent pumping cycles within the valley segment, r2 = 1, 2, ..., M; t0 represents the start time of the r1th cycle within the peak segment or the start time of the r2th cycle within the valley segment; ta represents the time from pumping in the r1th cycle within the peak segment until the pump efficiency reaches the minimum stable pump efficiency, then ta-t0 represents the intermittent pumping production time within the peak segment; tb represents the time from pumping in the r2th cycle within the valley segment until the pump efficiency reaches the minimum pump efficiency in the low-efficiency, high-consumption zone of the pumping unit, then tb-t0 represents the intermittent pumping production time within the valley segment; Sp represents the cross-sectional area of ​​the pumping pump plunger; s represents the polished rod stroke of the pumping unit; n represents the number of pumping unit operating strokes; η represents the pump efficiency, which is the ratio of the effective pump stroke to the polished rod stroke; k is the production controllability coefficient, k = 0.85~1.0; η t The minimum stable pump efficiency is the stable value of the pump efficiency when the target well is in continuous production; the left side of the intermittent pumping optimization model represents the sum of the peak production and valley production of the target well, and the right side of the intermittent pumping optimization model represents the controllable production rate when the target well is in continuous production. The preset control strategy constraints are as follows: The shutdown time is the same in the peak section and the valley section; The peak-segment inter-pumping production time is the time during which the target well is shut down from the start-up time until the pump efficiency stabilizes during the peak segment. The inter-well pumping production time in the valley-level section is the time from the start-up time of the target well in the valley-level section until it enters the low-efficiency, high-consumption zone and then shuts down.

3. The method according to claim 2, characterized in that, Before solving for the inter-valley pumping production time based on the preset inter-valley pumping optimization model, the following steps are also included: The intermediate sampling optimization model is processed to obtain a simplified intermediate sampling optimization model: N×(ta-t0)×(η0+η t ) / 2+M×(tb-t0)×(η0+2η t ) / 3≥k×1440×η t ; Where N represents the number of pumping cycles in the peak section, N=a×60 / [(ta-t0)+ts], ts represents the well shutdown time, a represents the peak section duration, M represents the number of pumping cycles in the valley section, M=(24-a)×60 / [(tb-t0)+ts], and η0 represents the pumping efficiency at the start time.

4. The method according to claim 3, characterized in that, The process of calculating the intermittent pumping production time in the valley-level section based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the intermittent pumping production time in the peak segment using an intermittent pumping optimization model includes: Based on the peak segment duration, the initial well shutdown duration, and the inter-peak segment pumping production duration, determine the initial peak segment pumping cycle number and the initial valley-level segment pumping cycle number. Based on the initial peak-segment pumping cycle number, the initial valley-smooth-segment pumping cycle number, the pumping efficiency at startup, and the minimum stable pumping efficiency, the production time of intermittent pumping in the valley-smooth-segment is solved using the simplified intermittent pumping optimization model.

5. The method according to claim 4, characterized in that, Also includes: The simplified intermittent pumping optimization model is transformed to obtain the equation regarding the intermittent pumping production time in the valley-flattening section: in, 6. The method according to any one of claims 1-5, characterized in that, If there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model to solve the problem again. If there is still no solution, the peak-segment inter-sampling production time will be used as the optimized valley-segment inter-sampling production time to obtain the optimized inter-sampling system. If a solution exists, the optimized intermittent sampling regime is obtained based on the solution of the intermittent sampling optimization model, including: If there is no initial solution, the controllable coefficients of the production liquid are selected in descending order within the preset range of controllable coefficient values, and then substituted into the intermittent pumping optimization model to solve the problem again. If the intermittent pumping optimization model still has no solution under the condition that the production controllability coefficient is minimized, then the peak segment intermittent pumping production time is taken as the optimized valley segment intermittent pumping production time, the initial shutdown time is taken as the optimized shutdown time, and the peak segment intermittent pumping production time is taken as the optimized peak segment intermittent pumping production time, thus obtaining the optimized intermittent pumping system. If the intermittent pumping optimization model has a solution under the condition of a controllable production coefficient selected in sequence, then the solution of the intermittent pumping optimization model is used as the optimized intermittent pumping production time in the valley-level section, the initial well shutdown time is used as the optimized well shutdown time, and the intermittent pumping production time in the peak section is used as the optimized intermittent pumping production time in the peak section, thus obtaining the optimized intermittent pumping system.

7. The method according to any one of claims 1-5, characterized in that, If an initial solution exists, the well stoppage time is increased by a preset time step within a preset well stoppage time range. Based on the updated well stoppage time, the process of obtaining a new peak-segment intermittent pumping production time and solving the intermittent pumping optimization model is repeated until no solution is found or the well stoppage time reaches its upper limit. Based on the solution of the previous intermittent pumping optimization model that yielded no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, the optimized intermittent pumping system is determined, including: If there is an initial solution, the well stop time is increased by a preset time step within the preset well stop time range. The process of obtaining a new peak segment inter-pumping production time and solving the inter-pumping optimization model based on the updated peak segment inter-pumping production time is repeated until there is no solution or the well stop time reaches the upper limit of the well stop time. If the intermittent pumping optimization model has no solution under the conditions of an updated well stoppage duration selected in sequence and a production controllability coefficient selected within the range of preset production controllability coefficient values, then the solution of the previous intermittent pumping optimization model with no solution is taken as the optimized valley-level intermittent pumping production duration, and the updated well stoppage duration and the updated peak-level intermittent pumping production duration when the previous intermittent pumping optimization model with no solution are taken as the optimized well stoppage duration and the optimized peak-level intermittent pumping production duration, thus obtaining the optimized intermittent pumping system; If the updated well stoppage time reaches the upper limit of the well stoppage time range, and the intermittent pumping optimization model still has a solution, then the current solution of the intermittent pumping optimization model is used as the optimized valley-level intermittent pumping production time, the upper limit of the well stoppage time is used as the optimized well stoppage time, and the updated peak-level intermittent pumping production time determined according to the upper limit of the well stoppage time is used as the optimized peak-level intermittent pumping production time, thus obtaining the optimized intermittent pumping system.

8. A smart intermittent pumping control device for oil pumping units operating under peak-valley flat electricity pricing, characterized in that, include: The first calculation module is used to collect the dynamometer card of the target well during the peak period of continuous pumping within a preset time length, and calculate the minimum stable pump efficiency based on the collected dynamometer card. The second calculation module is used to obtain the pumping efficiency at the start time when pumping is started after the initial shutdown time of the target well, collect the dynamometer diagram and calculate the pumping efficiency according to the preset time interval, record the time when pumping is started until the pumping efficiency reaches the minimum stable pumping efficiency, and calculate the peak-segment pumping production time. The model solving module is used to solve the inter-valley pumping production time based on the peak segment duration, the pump start-up efficiency, the minimum stable pump efficiency, the initial well shutdown duration, and the inter-valley pumping production time during the peak segment, using an inter-valley pumping optimization model. The first intermittent pumping optimization module is used to select the controllable coefficient of the production liquid in descending order within the preset range of controllable coefficient values ​​of the intermittent pumping optimization model when the intermittent pumping optimization model has no initial solution, and then substitute them into the intermittent pumping optimization model to solve it again. If there is still no solution, the peak-segment inter-sampling production time is used as the optimized valley-segment inter-sampling production time to obtain the optimized inter-sampling system; if there is a solution, the optimized inter-sampling system is obtained based on the solution of the inter-sampling optimization model. The second intermittent pumping optimization module is used to, when the intermittent pumping optimization model has an initial solution, increase the well stoppage time within a preset well stoppage time range according to a preset time step, obtain and, based on the updated well stoppage time, re-execute the above process to obtain a new peak segment intermittent pumping production time and perform the solution, until there is no solution or the well stoppage time reaches the upper limit of the well stoppage time. Based on the solution of the previous intermittent pumping optimization model that has no solution or the solution of the intermittent pumping optimization model under the condition of the upper limit of the well stoppage time, determine the optimized intermittent pumping system.

9. A computer-readable storage medium having a computer program / instructions stored thereon, characterized in that, When the computer program / instruction is executed by the processor, it implements the method for controlling inter-pumping of oil pumps under peak-valley-flat electricity pricing as described in any one of claims 1-7.

10. A computer program product comprising a computer program / instructions, characterized in that, When the computer program / instruction is executed by the processor, it implements the method for controlling inter-pumping of oil pumps under peak-valley-flat electricity pricing as described in any one of claims 1-7.

11. A computer device, comprising a memory, a processor, and a computer program stored in the memory, characterized in that, The processor executes the computer program to implement the method for controlling inter-pumping of oil pumps under peak-valley-flat electricity pricing as described in any one of claims 1-7.

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