Auxiliary oil extraction device

Abstract

The embodiment of the invention discloses an auxiliary oil extraction device. According to one specific implementation mode, the auxiliary oil extraction device comprises an inlet valve, a line sweeping valve, a pressure controller, an efflux pump, an outlet pressure meter, a flow meter, a check valve, an outlet stop valve and a control cabinet. The inlet valve is arranged at the inlet end of the pipeline system; the line sweeping valve and the inlet valve are connected in parallel to an inlet pipeline of the pipeline system, and the line sweeping valve is arranged in a hot water pipeline; the pressure controller is arranged in an inlet pipeline of the pipeline system; the efflux pump is arranged in the pipeline system; the outlet pressure gauge is arranged in an outlet pipeline of the pipeline system; the flowmeter, the check valve and the outlet stop valve are arranged on a downstream pipeline of the efflux pump in the pipeline system, and the outlet stop valve is arranged at the outlet end of the pipeline system; and the control cabinet is in communication connection with the pressure controller, the outlet pressure gauge, the efflux pump and the flow meter. According to the implementation mode, the problems of pipeline blockage and flow attenuation caused by fluctuation of wellhead pressure along with time and environmental factors can be relieved.

Description

Technical Field

[0001] Embodiments of the present disclosure relate to the technical field of oilfield development equipment, and in particular to auxiliary oil production equipment. Background Art

[0002] During the production process of oil wells, the wellhead pressure will gradually decrease due to environmental influences such as the decline of reservoir energy and temperature changes, which will affect the stable transportation of the medium. This phenomenon is more significant in the application of complex reservoirs and long-distance pipelines. Pipeline blockage will not only affect the production efficiency of oil wells, but may also lead to serious consequences such as equipment overload and system shutdown.

[0003] At present, there is no special production-aiding equipment for oil wellheads in the field of oilfield development equipment technology, and it is necessary to solve the problems of pipeline blockage and flow attenuation caused by fluctuations in wellhead pressure over time and environmental factors.

[0004] The above information disclosed in this Background section is only for enhancement of understanding of the background of the inventive concept and therefore it may contain information that does not form the prior art that is already known to a person of ordinary skill in the art. Summary of the invention

[0005] The content of this disclosure is used to introduce concepts in a brief form, which will be described in detail in the detailed implementation section below. The content of this disclosure is not intended to identify the key features or essential features of the technical solution claimed for protection, nor is it intended to limit the scope of the technical solution claimed for protection.

[0006] Some embodiments of the present disclosure provide auxiliary oil production devices to solve one or more of the technical problems mentioned in the above background technology section.

[0007] In a first aspect, some embodiments of the present disclosure provide an auxiliary oil production device, which includes: an inlet valve, a sweep valve, a pressure controller, an external transfer pump, an outlet pressure gauge, a flow meter, a check valve, an outlet cut-off valve and a control cabinet; the inlet valve is arranged at the inlet end of a pipeline system, and the inlet valve is configured to be able to open and close the inlet pipeline of the pipeline system; the sweep valve and the inlet valve are connected in parallel to the inlet pipeline of the pipeline system, and the sweep valve is arranged in a hot water pipeline; the pressure controller is arranged in the inlet pipeline of the pipeline system, and is configured to collect the inlet pressure of the pipeline system; The external transfer pump is arranged in the pipeline system, and is configured to transport the liquid from a single well introduced from the inlet pipeline to the downstream pipeline; the outlet pressure gauge is arranged in the outlet pipeline of the pipeline system, and is configured to collect the outlet pressure of the outlet pipeline; the flow meter, the check valve and the outlet cut-off valve are arranged in the downstream pipeline of the external transfer pump in the pipeline system, the outlet cut-off valve is arranged at the outlet end of the pipeline system, and the outlet cut-off valve is configured to open and close the outlet pipeline of the pipeline system; the control cabinet is communicatively connected with the pressure controller, the outlet pressure gauge, the external transfer pump and the flow meter.

[0008] Optionally, the auxiliary oil production device further comprises an inlet filter, and the inlet filter is arranged in the downstream pipeline of the pressure controller in the pipeline system.

[0009] Optionally, the auxiliary oil production device further includes a water content analyzer, which is disposed in the pipeline system, and the control cabinet is communicatively connected with the water content analyzer.

[0010] Optionally, the auxiliary oil production device further comprises a sampling valve, and the sampling valve is arranged in a branch of the pipeline system.

[0011] Optionally, the auxiliary oil production device further includes a damper and a pressure transmitter, wherein the damper is arranged at one end of the branch, the pressure transmitter is arranged at the other end of the branch, and the control cabinet is communicatively connected to the pressure transmitter.

[0012] Optionally, the external transfer pump includes a power end, a hydraulic end and a motor, the hydraulic end stores a pumping medium and a hydraulic medium, the pumping medium and the hydraulic medium are separated by a diaphragm, and the hydraulic end is also equipped with a liquid-gas valve.

[0013] Optionally, the control cabinet includes an acquisition module, an Internet of Things module, a frequency converter, a switching power supply and a display screen.

[0014] Optionally, the auxiliary oil production device also includes a common base and a skid house.

[0015] Optionally, the auxiliary oil production device also includes at least one of the following: electric heating, explosion-proof lighting, exhaust fan, and anti-theft lock.

[0016] Optionally, the control cabinet is configured to perform the following steps: acquiring the inlet pressure collected by the pressure controller; in response to determining that the inlet pressure is greater than a first preset pressure value, controlling the external transfer pump to perform a flow increase operation; in response to determining that the inlet pressure is less than a second preset pressure value, controlling the external transfer pump to perform a flow reduction operation; in response to determining that the inlet pressure is less than a target pressure value, controlling the external transfer pump to stop running.

[0017] The above-mentioned various embodiments of the present disclosure have the following beneficial effects: through the auxiliary oil production device of some embodiments of the present disclosure, the vacancy of dedicated auxiliary production equipment for oil wellheads in the technical field of oilfield development equipment is filled, and the problems of pipeline blockage and flow attenuation caused by fluctuations in wellhead pressure over time and environmental factors can be alleviated. The auxiliary oil production device of some embodiments of the present disclosure includes an inlet valve, a sweeping valve, a pressure controller, an external transfer pump, an outlet pressure gauge, a flow meter, a check valve, an outlet shut-off valve and a control cabinet; the inlet valve is arranged at the inlet end of the pipeline system, and the inlet valve is configured to be able to open and close the inlet pipeline of the pipeline system; the sweeping valve and the inlet valve are connected in parallel to the inlet pipeline of the pipeline system, and the sweeping valve is arranged in the hot water pipeline; the pressure controller is arranged in the inlet pipeline of the pipeline system and is configured to collect the inlet pressure of the pipeline system; the external transfer pump is arranged in the In the pipeline system, it is configured to transport the single well liquid introduced from the inlet pipeline to the downstream pipeline; the outlet pressure gauge is arranged in the outlet pipeline of the pipeline system and is configured to collect the outlet pressure of the outlet pipeline; the flow meter, the check valve and the outlet cut-off valve are arranged in the downstream pipeline of the external transfer pump in the pipeline system, the outlet cut-off valve is arranged at the outlet end of the pipeline system, and the outlet cut-off valve is configured to open and close the outlet pipeline of the pipeline system; the control cabinet is connected in communication with the pressure controller, the outlet pressure gauge, the external transfer pump and the flow meter. Thus, the digital auxiliary oil production system can be realized through the communication connection between the control cabinet and the pressure controller, the outlet pressure gauge, the external transfer pump and the flow meter, so that the pressure data, flow data and the oil delivery process can be easily obtained. In addition, because a sweeping valve is configured, the pipeline and the components along the way can be cleaned by conveying hot water, and the dirt and wax attached to the inner wall can be removed, so as to improve the fluidity of the conveying medium, thereby alleviating the pipeline blockage and flow attenuation problems caused by the fluctuation of the wellhead pressure over time and environmental factors. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] The above and other features, advantages and aspects of the embodiments of the present disclosure will become more apparent with reference to the following detailed description in conjunction with the accompanying drawings. Throughout the accompanying drawings, the same or similar reference numerals represent the same or similar elements. It should be understood that the drawings are schematic and that components and elements are not necessarily drawn to scale.

[0019] Figure 1 is a schematic structural diagram of some embodiments of the auxiliary oil production device according to the present disclosure;

[0020] Figure 2 It is a schematic diagram of the electronic equipment structure of a control cabinet of an auxiliary oil production device suitable for implementing some embodiments of the present disclosure. DETAILED DESCRIPTION

[0021] Embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although certain embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be construed as being limited to the embodiments set forth herein. On the contrary, these embodiments are provided to provide a more thorough and complete understanding of the present disclosure. It should be understood that the drawings and embodiments of the present disclosure are only for exemplary purposes and are not intended to limit the scope of protection of the present disclosure.

[0022] It should also be noted that, for ease of description, only the parts related to the invention are shown in the drawings. In the absence of conflict, the embodiments and features in the embodiments of the present disclosure can be combined with each other.

[0023] It should be noted that the concepts such as "first" and "second" mentioned in the present disclosure are only used to distinguish different devices, modules or units, and are not used to limit the order or interdependence of the functions performed by these devices, modules or units.

[0024] It should be noted that the modifications of "one" and "plurality" mentioned in the present disclosure are illustrative rather than restrictive, and those skilled in the art should understand that unless otherwise clearly indicated in the context, it should be understood as "one or more".

[0025] The names of the messages or information exchanged between multiple devices in the embodiments of the present disclosure are only used for illustrative purposes and are not used to limit the scope of these messages or information.

[0026] The present disclosure will be described in detail below with reference to the accompanying drawings and in conjunction with embodiments.

[0027] Figure 1 The schematic diagrams of the structures of some embodiments of the auxiliary oil production device according to the present disclosure are shown. Figure 1It includes an inlet valve 1, a sweep valve 2, a pressure controller 3, an inlet filter 4, a water content analyzer 5, an external transfer pump 6, a sampling valve 7, a damper 8, an outlet pressure gauge 9, a pressure transmitter 10, a flow meter 11, a check valve 12, an outlet cut-off valve 13 and a control cabinet 14.

[0028] In some embodiments, the auxiliary oil production device may include an inlet valve 1, a sweep valve 2, a pressure controller 3, an external transmission pump 6, an outlet pressure gauge 9, a flow meter 11, a check valve 12, an outlet cut-off valve 13 and a control cabinet 14.

[0029] In some embodiments, the inlet valve 1 is arranged at the inlet end of the pipeline system, and the inlet valve 1 is configured to open and close the inlet pipeline of the pipeline system. The inlet valve 1 can be arranged in the oil pipeline. The sweep valve 2 and the inlet valve 1 can be connected in parallel to the inlet pipeline of the pipeline system. The sweep valve 2 is arranged in the hot water pipeline. The sweep valve 2 can be used to open and close the hot water pipeline in the pipeline system. The inlet valve 1 and the sweep valve 2 can facilitate the maintenance and overhaul of the pump and the pipeline.

[0030] In some embodiments, the pressure controller 3 can be arranged in the inlet pipeline of the pipeline system and configured to collect the inlet pressure of the pipeline system. The pressure controller 3 can be used for pressure measurement and control of the inlet pipeline, and convert the measured pressure into a standard electrical signal, and the signal type can be 4-20mA+HART (with meter display).

[0031] In some embodiments, the external transfer pump 6 can be arranged in the pipeline system and configured to transfer the single well liquid introduced from the inlet pipeline to the downstream pipeline. The external transfer pump 6 can adopt a hydraulically driven diaphragm pump, which is mainly composed of a power end, a hydraulic end, and a motor. A polytetrafluoroethylene diaphragm is used to separate the pumping medium and the hydraulic medium to achieve leakage-free transportation. The pumping medium may include water, oil, and gas. The hydraulic medium may include hydraulic oil. The hydraulic end is equipped with a liquid-gas valve, and the lift, motion trajectory, and opening and closing of the valve can be controlled through a precise algorithm to achieve liquid-gas two-phase flow mixed transportation.

[0032] Optionally, the external transfer pump 6 may include a power end, a hydraulic end and a motor, the hydraulic end stores a pumping medium and a hydraulic medium, the pumping medium and the hydraulic medium are separated by a diaphragm, and the hydraulic end is also equipped with a liquid-gas valve.

[0033] In some embodiments, the outlet pressure gauge 9 may be disposed in the outlet pipeline of the pipeline system and configured to collect the outlet pressure of the outlet pipeline. The outlet pressure gauge 9 may be a stainless steel shock-resistant type and may also be provided with a root valve.

[0034] In some embodiments, the flow meter 11, the check valve 12 and the outlet shut-off valve 13 can be arranged in the downstream pipeline of the external transfer pump in the pipeline system. The outlet shut-off valve 13 can be arranged at the outlet end of the pipeline system. The outlet shut-off valve 13 can be configured to open and close the outlet pipeline of the pipeline system, so as to facilitate the maintenance and inspection of the pump and the pipeline. The above-mentioned flow meter 11 can be used to detect the instantaneous flow rate and total accumulated flow rate of the liquid, and convert it into a standard electrical signal proportional to the flow rate. The above-mentioned check valve 12 can be of a swing type or a vertical type, which can be used to prevent the backflow of liquid in the discharge pipeline, and isolate the discharge end of the pump from the system pressure, protect the system equipment and maintain the system pressure.

[0035] In some embodiments, the control cabinet 14 is connected to the pressure controller, the outlet pressure gauge, the external transmission pump and the flow meter. The control cabinet 14 can be a programmable logic controller. The control cabinet 14 can be provided with electronic components such as an acquisition module, an Internet of Things module, a frequency converter, a switching power supply, and a display screen. The acquisition module can be used to obtain data from various instruments and can include a sensor interface for connecting various instruments. The Internet of Things module can be used to achieve communication with the Internet, and can include but is not limited to: a processor or a microcontroller, a wireless communication module, a power management unit, a memory, an input and output interface, and an antenna. The frequency converter can be used to control the motor speed of the external transmission pump. The display screen can be a color LCD display. The control cabinet 14 can also realize human-computer dialogue function, real-time display of parameters, query parameter setting values, fault alarm and operation status display. By inputting digital and analog signals to the control cabinet 14 and programming, other operating states of the equipment can also be displayed. The control cabinet 14 can realize data display on site, data remote transmission and storage.

[0036] Optionally, the control cabinet may be configured to perform the following steps:

[0037] The first step is to obtain the inlet pressure collected by the pressure controller.

[0038] In the second step, in response to determining that the inlet pressure is greater than the first preset pressure value, the external transfer pump is controlled to perform a flow increase operation. Here, the flow increase operation can be an operation of increasing the first preset flow rate on the basis of the original flow rate. The flow rate can be the measured amount of liquid flowing through the pump, which can be expressed as a volume flow rate (such as cubic meters per hour m3 / h). The first preset pressure value can be 1.0MPa. The first preset pressure value and the first preset flow rate can be pre-set and are not specifically limited.

[0039] In the third step, in response to determining that the inlet pressure is less than the second preset pressure value, the external transfer pump is controlled to perform a flow reduction operation. Here, the flow reduction operation may be an operation of reducing the second preset flow rate based on the original flow rate. The second preset pressure value may be 0.5 MPa. The second preset flow rate and the second preset flow rate may be pre-set and are not specifically limited.

[0040] In the fourth step, in response to determining that the inlet pressure is less than the target pressure value, the external transmission pump is controlled to stop running. The target pressure value may be 0.3 MPa. The target pressure value may be pre-set and is not specifically limited. In this way, the wellhead pressure can be stabilized in a suitable range.

[0041] Optionally, the auxiliary oil production device further comprises a display screen, and the control cabinet may be configured to perform the following steps:

[0042] The first step is to obtain the inlet pressure sequence, outlet pressure sequence, flow sequence, and water information sequence collected by the pressure controller, the outlet pressure gauge, the flow meter, and the water analyzer within a preset time period. The inlet pressure sequence, the outlet pressure sequence, the flow sequence, and the water information sequence can be sequence data arranged in chronological order. The water information in the water information sequence can include but is not limited to water content.

[0043] The second step is to generate inlet pressure curve information according to the inlet pressure sequence. In practice, the data distribution of the inlet pressure sequence can be fitted to obtain a fitting function as the inlet pressure curve information.

[0044] The third step is to generate outlet pressure curve information according to the outlet pressure sequence. In practice, the data distribution of the outlet pressure sequence can be fitted to obtain a fitting function as the outlet pressure curve information.

[0045] In the fourth step, the inlet pressure curve corresponding to the inlet pressure curve information and the outlet pressure curve corresponding to the outlet pressure curve information are plotted in a preset pressure chart coordinate system to obtain a pressure change trend chart. The preset pressure chart coordinate system may be a coordinate system in which the vertical axis represents the pressure value and the horizontal axis represents the time step. The pressure change trend chart includes an inlet pressure curve and an outlet pressure curve. The inlet pressure curve may be a visual representation of the inlet pressure curve information. The outlet pressure curve may be a visual representation of the outlet pressure curve information.

[0046] The fifth step is to generate flow curve information according to the flow sequence. In practice, the data distribution of the flow sequence can be fitted to obtain a fitting function as the flow curve information.

[0047] Step 6: Draw a flow curve corresponding to the flow curve information in a preset flow chart coordinate system to obtain a flow change trend chart. The preset flow chart coordinate system may be a coordinate system in which the vertical axis represents the flow value and the horizontal axis represents the time step. The flow change trend chart includes a flow curve. The flow curve may be a visual representation of the flow curve information.

[0048] The seventh step is to generate moisture content curve information according to the moisture content information sequence. In practice, the data distribution of each moisture content included in the moisture content information sequence can be fitted to obtain a fitting function as the moisture content curve information.

[0049] In the eighth step, a moisture content curve corresponding to the moisture content curve information is drawn in a preset moisture content chart coordinate system to obtain a moisture content change trend chart. The preset moisture content chart coordinate system may be a coordinate system in which the vertical axis represents the moisture content and the horizontal axis represents the time step. The moisture content change trend chart includes a moisture content curve. The moisture content curve may be a visual representation of the moisture content curve information.

[0050] In step 9, the pressure change trend chart, the flow change trend chart and the water content change trend chart are displayed in the monitoring page of the display screen. The monitoring page also displays a report export control. The monitoring page can be a page for monitoring the measurement data of each instrument. The report export control can be a page control for summarizing the monitoring content in the form of a report.

[0051] In the tenth step, in response to detecting a selection operation acting on the report export control, an oil production monitoring report is generated according to the pressure change trend chart, the flow change trend chart and the water content change trend chart. In practice, the pressure change trend chart, the flow change trend chart and the water content change trend chart can be spliced ​​according to a preset graphic format, and then the spliced ​​content can be converted into a file in a preset format as an oil production monitoring report. For example, the preset graphic format can be a method of splicing icons and graphic names in sequence vertically. The preset format can be PDF. Here, there is no limitation on the preset graphic format and the specific setting of the preset format.

[0052] In the eleventh step, the oil production monitoring report is sent to at least one pre-bound terminal device. The terminal device may include but is not limited to: a mobile phone, a computer, and a tablet computer. Thus, the oil production monitoring report can be automatically generated at any stage of the generation process, and can be viewed on-site and remotely by technicians, and can be directly analyzed in many aspects through the visual curves in the oil production monitoring report, thereby improving the digitalization and intelligence level of the auxiliary oil production device.

[0053] In the process of adopting technical solutions to solve the technical problems mentioned in the background technology, the following technical problems are often accompanied: the fault type detection in the oil production process relies on manual analysis, and the fault needs to be handled manually, resulting in low accuracy of fault type detection and fault handling efficiency. In response to this technical problem, the conventional solution is generally to set judgment thresholds for each instrument corresponding to different types of faults, or to identify the fault type through conventional machine learning algorithms. However, the above conventional solutions still have the following problems: the method of setting the judgment threshold is relatively subjective, and the accuracy of detecting the fault type is poor; the method of identifying the fault type through conventional machine learning algorithms, the pipeline and the various instruments in the pipeline have a topological relationship, and the conventional machine learning algorithm cannot combine spatial associations, so it is impossible to mine the multi-level patterns in the spatial features, and the accuracy of detecting the fault type is poor.

[0054] Considering the problems of the above conventional solutions, facing the above technical problems: the fault type detection in the oil production process relies on manual analysis, and the fault needs to be handled manually, resulting in low accuracy of fault type detection and low efficiency of fault handling. Combined with the convenience of obtaining the topological relationship between the pipelines and instruments in the auxiliary oil production device, it can be decided to adopt the following solution.

[0055] Optionally, the auxiliary oil production device further includes at least one pipeline temperature sensor, at least one vibration sensor, and the control cabinet may be configured to perform the following steps:

[0056] The first step is to obtain an auxiliary oil production device model pre-modeled for the auxiliary oil production device and the pipeline system. The auxiliary oil production device model can be a graph data pre-modeled according to the components included in the auxiliary oil production device and the pipelines between the components, and can include nodes (i.e., model nodes) and edges. The various model nodes in the auxiliary oil production device model may include: an inlet valve node, a pressure controller node, an external transmission pump node, an outlet pressure gauge node, a flow meter node, a check valve node, an outlet shut-off valve node, a control cabinet node, a water analyzer node, at least one pipeline temperature sensor node, and at least one vibration sensor node. Each node can represent a corresponding instrument, sensor, or valve. The edge in the auxiliary oil production device model represents the pipeline corresponding to two model nodes in the pipeline system.

[0057] The second step is to respectively obtain the inlet pressure sequence, outlet pressure sequence, flow sequence, water content information sequence, pipeline temperature sequence group and vibration information sequence group collected by the pressure controller, the outlet pressure gauge, the flow meter, the water content analyzer, the at least one pipeline temperature sensor and the at least one vibration sensor within a preset time period. Each pipeline temperature sequence in the pipeline temperature sequence group may correspond to a pipeline temperature sensor. Each vibration information sequence in the vibration information sequence group may correspond to a vibration sensor.

[0058] The third step is to normalize the inlet pressure sequence, the outlet pressure sequence, the flow sequence, the water content information sequence, the pipeline temperature sequence group and the vibration information sequence group, respectively. Thus, the data can be unified into the same dimension, which is convenient for model calculation.

[0059] The fourth step is to associate the normalized inlet pressure sequence with the pressure controller node to update the pressure controller node in the auxiliary oil production device model. Thus, data association can be performed on the pressure controller node in the auxiliary oil production device model.

[0060] The fifth step is to associate the normalized outlet pressure sequence with the outlet pressure gauge node to update the outlet pressure gauge node in the auxiliary oil production device model. Thus, data association can be performed on the outlet pressure gauge node in the auxiliary oil production device model.

[0061] The sixth step is to associate the normalized flow sequence with the flow meter node to update the flow meter node in the auxiliary oil production device model. Thus, data association can be performed on the flow meter node in the auxiliary oil production device model.

[0062] The seventh step is to associate the normalized water information sequence with the water analyzer node to update the water analyzer node in the auxiliary oil production device model. Thus, data association can be performed on the water analyzer node in the auxiliary oil production device model.

[0063] In the eighth step, for each pipeline temperature sequence in the normalized pipeline temperature sequence group, the pipeline temperature sequence is associated with the pipeline temperature sensor node corresponding to the pipeline temperature sequence to update the pipeline temperature sensor node in the auxiliary oil production device model. In this way, data association can be performed on each pipeline temperature sensor node in the auxiliary oil production device model.

[0064] In the ninth step, for each vibration information sequence in the normalized vibration information sequence group, the vibration information sequence is associated with the vibration sensor node corresponding to the vibration information sequence to update the vibration sensor node in the auxiliary oil production device model. In this way, data association can be performed on each vibration sensor node in the auxiliary oil production device model.

[0065] The tenth step is to determine the connection information between each two model nodes in the auxiliary oil production device model according to the edge between the two model nodes in the auxiliary oil production device model. The above connection information can be the physical distance or logical association strength between the two model nodes, which can be understood as the edge weight. When constructing the auxiliary oil production device model, the weight of the edge between the two model nodes with a connection relationship can be set according to the physical distance or logical association strength of the two model nodes. For two model nodes without a connection relationship, the corresponding connection information can be 0.

[0066] In the eleventh step, an adjacency matrix corresponding to each model node is generated according to each determined connection information. In practice, each determined connection information can be combined into an adjacency matrix corresponding to each model node in the form of a matrix.

[0067] In the twelfth step, the data associated with the pressure controller node, the outlet pressure gauge node, the flow meter node, the water analyzer node, the at least one pipeline temperature sensor node and the at least one vibration sensor node in the updated auxiliary oil production device model and the adjacency matrix are input into the spatiotemporal attention mechanism layer included in the pre-trained oil production fault detection model to obtain an updated node feature matrix. Wherein, the oil production fault detection model includes the spatiotemporal attention mechanism layer, the hierarchical graph convolution network, the cross-layer jump connection layer, the aggregation layer and the classification layer. The oil production fault detection model can be a neural network model that takes the associated data of each node as input and the oil production fault information as output. The oil production fault detection model can be a graph neural network model. The oil production fault information can characterize the fault type. The above-mentioned spatiotemporal attention mechanism layer can include a spatiotemporal attention module of the self-attention mechanism combining time series data and spatial relations. The dimension of all the associated data input can be N*T*F. Wherein, N can be the number of nodes. T can be the time step of the time series data. F can be the number of features of the node. The dimension of the updated node feature matrix can be N*F'. F' can represent the number of features of the changed node. The updated node feature matrix contains the understanding of the temporal and spatial context, and the feature space may change. The spatiotemporal attention mechanism layer learns which time points and neighboring nodes are most critical to the state of the current node. This layer can identify abnormal temporal patterns or spatial associations, thereby helping to locate potential fault points.

[0068] In the thirteenth step, the updated node feature matrix and the adjacency matrix are input into the hierarchical graph convolutional network to obtain multi-scale feature representation information. The hierarchical graph convolutional network may include a multi-scale graph convolutional layer. Specifically, the hierarchical graph convolutional network may be a series of GCN layers at different levels of abstraction, which gradually extract features from local to global. The multi-scale feature representation information may be a series of feature vectors at different levels of abstraction, usually represented in a list form. Each element is an N*F” matrix, corresponding to a different hierarchical level. F” may represent the number of features of the changed node. Low-level GCN layers may focus on local interactions between directly adjacent nodes, while high-level GCN layers may capture global patterns over a larger range. This helps to discover situations that appear normal locally but appear abnormal over a wider range, such as leaks or blockages affecting multiple nodes.

[0069] In the fourteenth step, the data associated with the pressure controller node, the outlet pressure gauge node, the flow meter node, the water analyzer node, the at least one pipeline temperature sensor node and the at least one vibration sensor node in the updated auxiliary oil production device model and the multi-scale feature representation information are input into the cross-layer jump connection layer to obtain comprehensive feature representation information. Among them, the cross-layer jump connection layer can be a residual connection layer, which allows information to be directly transmitted from the shallow layer to the deep layer, prevents the gradient from disappearing and retains important features. The comprehensive feature representation information can be a feature matrix that finally integrates all levels of information. The cross-layer jump connection layer can ensure that the model does not lose important local details by maintaining the integrity of the original features and the intermediate layer features, and can also make full use of the complex patterns learned at the high level, which is crucial for accurate detection of early faults.

[0070] In step 15, the comprehensive feature representation information is input into the aggregation layer to obtain dimension-reduced feature representation information. The aggregation layer may be a graph pooling layer, which can reduce the number of nodes while retaining key information, such as sampling or aggregation operations based on node importance. The aggregation layer reduces the dimension and focuses on the key areas where failures are most likely to occur, thereby improving the efficiency and accuracy of subsequent classifiers.

[0071] In the sixteenth step, the dimension reduction feature representation information is input into the classification layer to obtain oil production fault information. The classification layer may be a fully connected layer or a multi-layer perceptron, which is responsible for mapping the dimension-reduced features to specific categories, i.e., "normal" or specific fault types. The oil production fault information may include a fault probability distribution. The fault probability distribution may characterize the probabilities of the auxiliary oil production device belonging to each category.

[0072] Step 17: In response to determining that the oil production fault information satisfies a preset fault handling condition, a fault handling strategy corresponding to the oil production fault information is determined. The preset fault handling condition may be that the maximum fault probability distribution in the oil production fault information is greater than a preset threshold. The fault handling strategy corresponding to each fault type may be pre-set. The fault handling strategy may include a model node to be controlled and corresponding fault handling parameter information. The fault handling parameter information may include control parameters corresponding to the model node.

[0073] Step 18: Control the operation component corresponding to the model node to perform a fault handling operation according to the fault handling parameter information. The operation component corresponding to the model node may be a valve, a transmission pump or a controller corresponding to the model node.

[0074] The above-mentioned first step to the eighteenth step, as an inventive point of an embodiment of the present disclosure, solves the problem that "the fault type detection in the oil production process relies on manual analysis and needs to manually handle the fault, resulting in low accuracy of fault type detection and low efficiency of fault handling". The factors that lead to low accuracy of fault type detection and low efficiency of fault handling are often as follows: the fault type detection in the oil production process relies on manual analysis and needs to manually handle the fault. If the above factors are solved, the effect of improving the accuracy of fault type detection and fault handling efficiency can be achieved. In order to achieve this effect, the present disclosure uses the topological structure data of the auxiliary oil production device to construct an auxiliary oil production device model of the graph data type, and designs an innovative graph neural network structure, which can identify abnormal time patterns or spatial associations, further mine the multi-level patterns in these features, including local and global information, to ensure that important features are not ignored, and fuse all levels of information together, focus on key areas by reducing the number of nodes, simplify the problem, and finally judge whether the auxiliary oil production device has a fault based on the reduced-dimensional features, and output the corresponding probability. Therefore, the innovative graph neural network structure can more accurately identify potential faults in the oil well pipeline system. At the same time, it can also use the identified fault type to automatically determine and handle the fault. Thereby improving the accuracy of fault type detection and the efficiency of fault handling.

[0075] Optionally, the auxiliary oil production device may further include an inlet filter 4. The inlet filter 4 may be disposed in the downstream pipeline of the pressure controller 3 in the pipeline system. The inlet filter 4 may be used to prevent larger solid particles, mechanical impurities, etc. from entering the medium cavity of the external transport pump to protect the diaphragm and prevent the one-way valve and the outlet pipeline from being blocked. For example, the inlet filter 4 may be a basket filter with a mesh size of 30 to 80.

[0076] Optionally, the auxiliary oil production device further includes a water content analyzer 5, which is arranged in the pipeline system, and the control cabinet is in communication connection with the water content analyzer. For example, the water content analyzer can be arranged in the upstream pipeline of the external transmission pump 6. The water content analyzer 5 can use an evaporation method to convert the measured water content data into a standard electrical signal.

[0077] Optionally, the auxiliary oil production device further comprises a sampling valve 7, which can be arranged in a branch of the pipeline system. The sampling valve 7 can be used to collect liquid in the pipeline as a sample for chemical analysis.

[0078] Optionally, the auxiliary oil production device may also include a damper 8 and a pressure transmitter 10. The damper 8 may be arranged at one end of the branch. The damper 8 may be a pre-pressurized structure, and may use elastic elements such as a bladder or a diaphragm to separate the gas and the conveying medium, and utilize the compression and expansion of the gas to store or release a portion of the liquid to achieve the effect of reducing the flow unevenness and pressure pulses in the pipeline. The pressure transmitter 10 may be arranged at the other end of the branch. The pressure transmitter 10 may be used for pressure measurement and control of the outlet pipeline system, and may convert the measured pressure into a standard electrical signal, and the signal type may be 4-20 mA+HART (with a meter display). The control cabinet 14 is communicatively connected to the pressure transmitter 10.

[0079] Optionally, the auxiliary oil production device may also include a common base and a skid house. The auxiliary oil production device may be placed on the common base and inside the skid house. The common base may be a platform-type base. The skid house may be a house structure that can accommodate the auxiliary oil production device. Here, there is no limitation on the specific materials of the common base and the skid house. For example, the common base may be a prefabricated steel-concrete structure or a steel structure frame. The skid house may include but is not limited to steel, sandwich panels, and aluminum alloys. Thus, the auxiliary oil production device may have adaptability to more environmental conditions, enabling it to cope with more extreme weather and engineering conditions, and ensuring that it can operate stably in harsh environments such as high temperature, low temperature, and drastic changes in humidity.

[0080] Optionally, the auxiliary oil production device may also include but is not limited to at least one of the following: electric heating, explosion-proof lighting, exhaust fan, and anti-theft lock. The electric heating can heat the pipeline system. The explosion-proof lighting, exhaust fan, and anti-theft lock can be set in the pry room.

[0081] The above-mentioned various embodiments of the present disclosure have the following beneficial effects: through the auxiliary oil production device of some embodiments of the present disclosure, the vacancy of dedicated auxiliary production equipment for oil wellheads in the technical field of oilfield development equipment is filled, and the problems of pipeline blockage and flow attenuation caused by fluctuations in wellhead pressure over time and environmental factors can be alleviated. The auxiliary oil production device of some embodiments of the present disclosure includes an inlet valve, a sweeping valve, a pressure controller, an external transfer pump, an outlet pressure gauge, a flow meter, a check valve, an outlet shut-off valve and a control cabinet; the inlet valve is arranged at the inlet end of the pipeline system, and the inlet valve is configured to be able to open and close the inlet pipeline of the pipeline system; the sweeping valve and the inlet valve are connected in parallel to the inlet pipeline of the pipeline system, and the sweeping valve is arranged in the hot water pipeline; the pressure controller is arranged in the inlet pipeline of the pipeline system and is configured to collect the inlet pressure of the pipeline system; the external transfer pump is arranged in the In the pipeline system, it is configured to transport the single well liquid introduced from the inlet pipeline to the downstream pipeline; the outlet pressure gauge is arranged in the outlet pipeline of the pipeline system and is configured to collect the outlet pressure of the outlet pipeline; the flow meter, the check valve and the outlet cut-off valve are arranged in the downstream pipeline of the external transfer pump in the pipeline system, the outlet cut-off valve is arranged at the outlet end of the pipeline system, and the outlet cut-off valve is configured to open and close the outlet pipeline of the pipeline system; the control cabinet is connected in communication with the pressure controller, the outlet pressure gauge, the external transfer pump and the flow meter. Thus, the digital auxiliary oil production system can be realized through the communication connection between the control cabinet and the pressure controller, the outlet pressure gauge, the external transfer pump and the flow meter, so that the pressure data, flow data and the oil delivery process can be easily obtained. In addition, because a sweeping valve is configured, the pipeline and the components along the way can be cleaned by conveying hot water, and the dirt and wax attached to the inner wall can be removed, so as to improve the fluidity of the conveying medium, thereby alleviating the pipeline blockage and flow attenuation problems caused by the fluctuation of the wellhead pressure over time and environmental factors.

[0082] Reference below Figure 2 , which shows a schematic diagram of the structure of an electronic device 200 (eg, a computing device in a control cabinet) of an auxiliary oil production device suitable for implementing some embodiments of the present disclosure. Figure 2 The electronic device shown is only an example and should not bring any limitation to the functions and scope of use of the embodiments of the present disclosure.

[0083] like Figure 2As shown, the electronic device 200 may include a processing device 201 (e.g., a central processing unit, a graphics processing unit, etc.), which can perform various appropriate actions and processes according to a program stored in a read-only memory (ROM) 202 or a program loaded from a storage device 208 to a random access memory (RAM) 203. In the RAM 203, various programs and data required for the operation of the electronic device 200 are also stored. The processing device 201, the ROM 202, and the RAM 203 are connected to each other via a bus 204. An input / output (I / O) interface 205 is also connected to the bus 204.

[0084] Typically, the following devices may be connected to the I / O interface 205: an input device 206 including, for example, a touch screen, a touch pad, a keyboard, a mouse, a camera, a microphone, an accelerometer, a gyroscope, etc.; an output device 207 including, for example, a liquid crystal display (LCD), a speaker, a vibrator, etc.; a storage device 208 including, for example, a magnetic tape, a hard disk, etc.; and a communication device 209. The communication device 209 may allow the electronic device 200 to communicate with other devices wirelessly or by wire to exchange data. Although Figure 2 The electronic device 200 is shown with various devices, but it should be understood that it is not required to implement or possess all the devices shown. More or fewer devices may be implemented or possessed instead. Figure 2 Each block shown in the figure may represent one device, or may represent multiple devices as required.

[0085] In particular, according to some embodiments of the present disclosure, the process described above with reference to the flowchart can be implemented as a computer software program. For example, some embodiments of the present disclosure include a computer program product, which includes a computer program carried on a computer-readable medium, and the computer program contains program code for executing the method shown in the flowchart. In some such embodiments, the computer program can be downloaded and installed from the network through the communication device 209, or installed from the storage device 208, or installed from the ROM 202. When the computer program is executed by the processing device 201, the above-mentioned functions defined in the method of some embodiments of the present disclosure are executed.

[0086] It should be noted that the computer-readable medium recorded in some embodiments of the present disclosure may be a computer-readable signal medium or a computer-readable storage medium or any combination of the above two. The computer-readable storage medium may be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, device or device, or any combination of the above. More specific examples of computer-readable storage media may include, but are not limited to: an electrical connection with one or more wires, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the above. In some embodiments of the present disclosure, a computer-readable storage medium may be any tangible medium containing or storing a program that can be used by or in combination with an instruction execution system, device or device. In some embodiments of the present disclosure, a computer-readable signal medium may include a data signal propagated in a baseband or as part of a carrier wave, which carries a computer-readable program code. This propagated data signal may take a variety of forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination of the above. The computer readable signal medium may also be any computer readable medium other than a computer readable storage medium, which may send, propagate or transmit a program for use by or in conjunction with an instruction execution system, apparatus or device. The program code contained on the computer readable medium may be transmitted using any suitable medium, including but not limited to: wires, optical cables, RF (radio frequency), etc., or any suitable combination of the above.

[0087] In some embodiments, the client and the server may communicate using any currently known or future developed network protocol such as HTTP (HyperText Transfer Protocol), and may be interconnected with any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include a local area network ("LAN"), a wide area network ("WAN"), an internet (e.g., the Internet), and a peer-to-peer network (e.g., an ad hoc peer-to-peer network), as well as any currently known or future developed network.

[0088] The computer-readable medium may be included in the electronic device; or it may exist independently without being assembled into the electronic device. The computer-readable medium carries one or more programs. When the one or more programs are executed by the electronic device, the electronic device: obtains the inlet pressure collected by the pressure controller; in response to determining that the inlet pressure is greater than the first preset pressure value, controls the external transfer pump to perform a flow increase operation; in response to determining that the inlet pressure is less than the second preset pressure value, controls the external transfer pump to perform a flow reduction operation; in response to determining that the inlet pressure is less than the target pressure value, controls the external transfer pump to stop running.

[0089] Computer program code for performing the operations of some embodiments of the present disclosure may be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages, such as Java, Smalltalk, C++, and conventional procedural programming languages, such as "C" or similar programming languages. The program code may be executed entirely on a user's computer, partially on a user's computer, as a separate software package, partially on a user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving a remote computer, the remote computer may be connected to the user's computer via any type of network, including a local area network (LAN) or a wide area network (WAN), or may be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0090] The flow chart and block diagram in the accompanying drawings illustrate the possible architecture, function and operation of the system, method and computer program product according to various embodiments of the present disclosure. In this regard, each square box in the flow chart or block diagram can represent a module, a program segment or a part of a code, and the module, the program segment or a part of the code contains one or more executable instructions for realizing the specified logical function. It should also be noted that in some implementations as replacements, the functions marked in the square box can also occur in a sequence different from that marked in the accompanying drawings. For example, two square boxes represented in succession can actually be executed substantially in parallel, and they can sometimes be executed in the opposite order, depending on the functions involved. It should also be noted that each square box in the block diagram and / or flow chart, and the combination of the square boxes in the block diagram and / or flow chart can be implemented with a dedicated hardware-based system that performs a specified function or operation, or can be implemented with a combination of dedicated hardware and computer instructions.

[0091] The functions described above herein may be performed at least in part by one or more hardware logic components. For example, without limitation, exemplary types of hardware logic components that may be used include: field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), complex programmable logic devices (CPLDs), and the like.

[0092] The above descriptions are only some preferred embodiments of the present disclosure and an explanation of the technical principles used. Those skilled in the art should understand that the scope of the invention involved in the embodiments of the present disclosure is not limited to the technical solutions formed by a specific combination of the above-mentioned technical features, but should also cover other technical solutions formed by any combination of the above-mentioned technical features or their equivalent features without departing from the above-mentioned inventive concept. For example, the above-mentioned features are replaced with the technical features with similar functions disclosed in the embodiments of the present disclosure (but not limited to) and the technical solutions formed.

Claims

1. An auxiliary oil production device, characterized in that: The auxiliary oil production device includes: an inlet valve, a sweep valve, a pressure controller, an external transmission pump, an outlet pressure gauge, a flow meter, a check valve, an outlet cut-off valve and a control cabinet; The inlet valve is arranged at the inlet end of the pipeline system, and the inlet valve is configured to open and close the inlet pipeline of the pipeline system; The sweep valve and the inlet valve are connected in parallel to the inlet pipeline of the pipeline system, and the sweep valve is arranged in the hot water pipeline; The pressure controller is disposed in the inlet pipeline of the pipeline system and is configured to collect the inlet pressure of the pipeline system; The external transfer pump is arranged in the pipeline system and is configured to transfer the liquid from a single well introduced from the inlet pipeline to the downstream pipeline; The outlet pressure gauge is disposed in the outlet pipeline of the pipeline system and is configured to collect the outlet pressure of the outlet pipeline; The flow meter, the check valve and the outlet cut-off valve are arranged in the downstream pipeline of the external transfer pump in the pipeline system, the outlet cut-off valve is arranged at the outlet end of the pipeline system, and the outlet cut-off valve is configured to open and close the outlet pipeline of the pipeline system; The control cabinet is communicatively connected with the pressure controller, the outlet pressure gauge, the external transmission pump and the flow meter.

2. The auxiliary oil production device according to claim 1, characterized in that: The auxiliary oil production device further includes an inlet filter, which is disposed in a downstream pipeline of the pressure controller in the pipeline system.

3. The auxiliary oil production device according to claim 1, characterized in that: The auxiliary oil production device also includes a water content analyzer, which is arranged in the pipeline system, and the control cabinet is communicatively connected with the water content analyzer.

4. The auxiliary oil production device according to claim 1, characterized in that: The auxiliary oil production device further comprises a sampling valve, which is arranged in a branch of the pipeline system.

5. The auxiliary oil production device according to claim 4, characterized in that: The auxiliary oil production device also includes a damper and a pressure transmitter. The damper is arranged at one end of the branch, and the pressure transmitter is arranged at the other end of the branch. The control cabinet is communicatively connected with the pressure transmitter.

6. The auxiliary oil production device according to claim 1, characterized in that: The external transfer pump comprises a power end, a hydraulic end and a motor. The hydraulic end stores a pumping medium and a hydraulic medium. The pumping medium and the hydraulic medium are separated by a diaphragm. The hydraulic end is also equipped with a liquid-gas valve.

7. The auxiliary oil production device according to claim 1, characterized in that: The control cabinet includes an acquisition module, an Internet of Things module, a frequency converter, a switching power supply and a display screen.

8. The auxiliary oil production device according to claim 1, characterized in that: The auxiliary oil production device also includes a common base and a skid house.

9. The auxiliary oil production device according to claim 1, characterized in that: The auxiliary oil production device also includes at least one of the following: electric heating, explosion-proof lighting, exhaust fan, and anti-theft lock.

10. The auxiliary oil production device according to any one of claims 1 to 9, characterized in that: The control cabinet is configured to perform the following steps: Obtaining the inlet pressure collected by the pressure controller; In response to determining that the inlet pressure is greater than a first preset pressure value, controlling the external transfer pump to perform a flow rate increasing operation; In response to determining that the inlet pressure is less than a second preset pressure value, controlling the external transfer pump to perform a flow reduction operation; In response to determining that the inlet pressure is less than the target pressure value, the external transfer pump is controlled to stop operating.

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