Intelligent diagnosis control of oil and gas field production station metering equipment

Abstract

This invention discloses an intelligent diagnostic control system for metering equipment in oil and gas field production stations, comprising multiple single-well metering devices, a total metering device, a communication module, a local control module, and a remote server. Each single-well metering device is connected at one end to an input branch pipe, which is connected to the discharge pipe of the corresponding oil and gas well. Each single-well metering device is also connected at the other end to an output branch pipe, which is connected to the main pipe. The system further includes a field diagnostic module for single-well metering devices, a field diagnostic module for the total metering device, and an online calibration module. Based on the current status of the single-well metering devices and the total metering device, the remote server sends control signals to the local control module to stop the operation of either the single-well metering device or the total metering device, and controls the online calibration module to perform online calibration of either the single-well metering device or the total metering device, or controls the single-well metering device or the total metering device to stop operation and then perform maintenance.

Description

Technical Field

[0001] This invention relates to the field of management technology for metering equipment at oil and gas field stations, and specifically to an intelligent diagnostic control system for metering equipment at oil and gas field production stations. Background Technology

[0002] Oil and gas fields can extract both oil and natural gas. At oil and gas production stations, it's necessary to measure the oil and gas volume of individual wells and the total oil and gas volume. Therefore, individual well metering equipment is required in each well, and a total metering device is needed on the main pipeline. Both individual and total metering devices may experience inaccurate readings or malfunctions during long-term use. The conventional approach is to maintain the metering equipment through regular inspections by staff, which is labor-intensive and inefficient. Furthermore, when the metering equipment is inaccurate and requires calibration, offline calibration is typically used, which is inconvenient for installation and disassembly, has a long calibration cycle, and may even affect oil and gas production. Summary of the Invention

[0003] To address the aforementioned shortcomings, this invention provides an intelligent diagnostic and control system for metering equipment in oil and gas field production stations, featuring online diagnostics and calibration capabilities. Each individual well metering device and the overall metering system is equipped with a separate on-site diagnostic module for both. This allows for real-time monitoring of both devices, eliminating the need for regular inspections by staff, reducing workload and saving manpower. Furthermore, when calibration is required for either device, online calibration can be performed without disassembling the equipment, minimizing calibration time and impact on oil and gas production. The use of a single online calibration module for both devices further reduces costs and saves installation space.

[0004] To achieve the above objectives, the present invention provides the following technical solution:

[0005] An intelligent diagnostic and control system for metering equipment at an oil and gas field production station includes multiple single-well metering devices, a total metering device, a communication module, a local control module, and a remote server. One end of each single-well metering device is connected to an input branch pipe, which is connected to the discharge pipe of the corresponding oil and gas well. The other end of each single-well metering device is connected to an output branch pipe, which is connected to a main pipe. The total metering device is mounted on the main pipe. The system also includes a field diagnostic module for single-well metering devices, a field diagnostic module for the total metering device, and an online calibration module. The field diagnostic module for single-well metering devices is used to monitor the operating information of the single-well metering devices in real time, and the field diagnostic module for the total metering device is used to monitor the total metering device in real time. The operational information of both the single-well metering device and the total metering device is transmitted to a remote server via a communication module. The remote server determines the current status of each device based on this information, including normal operation, requiring calibration, or malfunction. Based on the current status, the remote server sends a control signal to the local control module. The local control module then stops the operation of either the single-well metering device or the total metering device and controls the online calibration module to perform online calibration, or stops the device for maintenance.

[0006] The beneficial effects of this invention are as follows: Each single-well metering device and the total metering device are equipped with a single-well metering device field diagnostic module and a total metering device field diagnostic module, respectively. This allows for real-time monitoring of the single-well metering devices and the total metering devices, eliminating the need for regular inspections by staff, reducing workload, and saving manpower. Furthermore, when the single-well metering device or the total metering device is detected to require calibration, it can be calibrated online through the online calibration module, eliminating the need to disassemble the single-well metering device or the total metering device. This shortens the calibration time and reduces the impact on oil and gas production. Moreover, the use of a single online calibration module for both the single-well metering device and the total metering device reduces costs and saves installation space.

[0007] This invention equips each individual well metering device and the total metering device with a separate on-site diagnostic module. This allows for real-time monitoring of both devices, eliminating the need for regular inspections by staff, reducing workload and saving manpower. Furthermore, when calibration is required, it can be performed online via an online calibration module, eliminating the need to disassemble the devices. This shortens calibration time and minimizes impact on oil and gas production. Moreover, using a single online calibration module for both devices reduces costs and saves installation space. The remote server stores a first flow range threshold and a second flow range threshold, with the second flow range threshold having a larger range than the first flow range threshold. Based on these two flow range thresholds, it can be determined whether each single-well metering device is in normal operation, exceeds the first flow range threshold requiring calibration, or may have a fault requiring maintenance. The determination method for the total metering device is the same as that for the single-well metering device. This invention uses the above method to determine the operating status of both single-well metering devices and the total metering device; and through the cooperation of the isolator and the online calibration module, it achieves online calibration of the metering devices.

[0008] This invention provides an intelligent diagnostic control system for metering equipment in oil and gas field production stations, featuring an alarm module with multiple alarm prompt functions, specifically including the following: if calibration is required, the alarm module issues a calibration prompt; if a single-well metering device or the total metering device malfunctions, the alarm module issues a metering device malfunction alarm; if the remote server cannot receive single-well flow information and total flow information, the remote server sends a communication failure command to the local control module, which then controls the alarm module to issue a communication failure alarm. In this embodiment, the alarm module uses an alarm that flashes different colored alarm lights to correspond to different alarm prompts. In other embodiments, alarms can also be voice-activated, with different prompts using different voice announcements. Attached Figure Description

[0009] Figure 1 This is a schematic block diagram of an intelligent diagnostic control system for metering equipment at oil and gas field production stations according to the present invention. Detailed Implementation

[0010] In the following, the terms “comprising” or “may include” as used in various embodiments of the invention indicate the presence of an inventive function, operation, or element, and do not limit the addition of one or more functions, operations, or elements. Furthermore, as used in various embodiments of the invention, the terms “comprising,” “having,” and their cognates are intended only to indicate a specific feature, number, step, operation, element, component, or combination of the foregoing, and should not be construed as primarily excluding the presence of one or more other features, numbers, steps, operations, elements, components, or combinations of the foregoing, or adding one or more combinations of the foregoing.

[0011] The terminology used in the various embodiments of the invention is for the purpose of describing particular embodiments only and is not intended to limit the various embodiments of the invention. Unless otherwise specified, all terms (including technical and scientific terms) used herein have the same meaning as commonly understood by one of ordinary skill in the art to which the various embodiments of the invention pertain. The terms (such as those defined in commonly used dictionaries) are to be interpreted as having the same meaning as in the context of the relevant technical field and are not to be interpreted as having an idealized or overly formal meaning unless clearly defined in the various embodiments of the invention.

[0012] To make the objectives, technical solutions, and advantages of this invention clearer, the invention will be further described in detail below with reference to embodiments and accompanying drawings. The illustrative embodiments and descriptions of this invention are for illustrative purposes only and are not intended to limit the invention.

[0013] like Figure 1 As shown,

[0014] Example 1

[0015] As attached Figure 1 As shown: The intelligent diagnostic control system for metering equipment at oil and gas field production stations disclosed in this embodiment includes multiple single-well metering devices, a total metering device, a communication module, a local control module, a remote server, a field diagnostic module for single-well metering devices, a field diagnostic module for the total metering device, an online calibration module, and an alarm module.

[0016] Each of the single-well metering devices is connected at one end to an input branch pipe, which is connected to the discharge pipe of the corresponding oil and gas well. The other end of each single-well metering device is connected to an output branch pipe, which is connected to the main pipe. The main metering device is installed on the main pipe and also includes a bypass pipe. One end of the bypass pipe is connected to the discharge pipe of the oil and gas well, and the other end is connected to the main pipe. A first valve is installed on the bypass pipe, and a second valve is installed on the input branch pipe. When the single-well metering device is operating normally, the first valve is closed and the second valve is open. When the single-well metering device stops operating, the local control module synchronously controls the first valve to open and the second valve to close, thereby achieving oil and gas transportation through the bypass pipe. In this embodiment, a gas-liquid separation metering and oil-water content measurement device is also installed on the main pipe to facilitate the detection of oil-water content and gas-liquid two-phase flow rate in the main pipe.

[0017] In this embodiment, online diagnosis and online calibration of the single-well metering equipment and the total metering equipment are achieved in the following way: the single-well metering equipment field diagnosis module is used to monitor the operation information of the single-well metering equipment in real time, and the total metering equipment field diagnosis module is used to monitor the operation information of the total metering equipment in real time. The operation information of the single-well metering equipment and the total metering equipment are transmitted to the remote server through the communication module. The remote server determines the current status of the single-well metering equipment and the total metering equipment based on the operation information of the single-well metering equipment and the total metering equipment, respectively. The current status includes normal operation, calibration required, or fault. The remote server sends a control signal to the local control module based on the current status of the single-well metering equipment and the total metering equipment. The local control module controls the single-well metering equipment or the total metering equipment to stop operating according to the control signal, and controls the online calibration module to perform online calibration of the single-well metering equipment or the total metering equipment, or controls the single-well metering equipment or the total metering equipment to stop operating and then perform maintenance.

[0018] The diagnostic method involving the on-site diagnostic module for single-well metering equipment and the remote server is as follows: The operational information includes the flow rate, temperature, and pressure information of the single-well metering equipment, as well as the total flow rate, temperature, and pressure information of the total metering equipment. For each single well, the remote server stores a first flow range threshold and a second flow range threshold. The range of the second flow range threshold is greater than that of the first flow range threshold. The remote server compares the flow rate information of each single-well metering equipment with the first and second flow range thresholds. If the flow rate information is within the first flow range threshold, the single-well metering equipment is judged to be operating normally. If the flow rate information exceeds the first flow range threshold but is less than the second flow range threshold, the single-well metering equipment is judged to need calibration. If the flow rate information exceeds the second flow range threshold or the pressure or temperature is out of range, the single-well metering equipment is judged to be faulty.

[0019] The diagnostic method of the total metering equipment field diagnostic module and the remote server is as follows: The remote server is set with a first total flow threshold and a second total flow threshold. The remote server compares the flow information of the total metering equipment with the first total flow range threshold and the second total flow range threshold. If it is within the first total flow threshold, the total metering equipment is judged to be operating normally. If it exceeds the first total flow range threshold but is less than the second total flow range threshold, the total metering equipment is judged to need calibration. If it exceeds the second total flow range threshold or the pressure or temperature is out of range, the total metering equipment is judged to be faulty.

[0020] In this embodiment, the online calibration module is calibrated as follows: the single-well metering device and the total metering device collect the single-well flow rate and total flow rate respectively and send them to the isolator, which then sends them to the remote server. During calibration, the online calibration module sends a standard current signal to the isolator and reads back the isolator's output signal. If the isolator's output signal is within the standard range, the calibration is completed.

[0021] The alarm module in this embodiment has multiple alarm prompt functions, specifically including the following: if calibration is required, the alarm module issues a calibration prompt message; if a single-well metering device or the total metering device malfunctions, the alarm module issues a metering device malfunction alarm message; if the remote server cannot receive single-well flow information and total flow information, the remote server issues a communication failure command to the local control module, and the local control module controls the alarm module to issue a communication failure alarm. In this embodiment, the alarm module uses an alarm that can flash different colored alarm lights to correspond to different alarm prompts. In other embodiments, alarms can also be voice alarms, with different prompts using different voice broadcasts.

[0022] In this embodiment, in order to ensure that the collection of total flow and single-well flow is not affected when the total metering device or the single-well metering device is not running, the following measures are taken: When the total metering device is not running, the remote server summarizes and calculates the total flow by receiving the single-well flow information collected by each single-well metering device.

[0023] When a single-well metering device stops operating, the remote server calculates the flow rate of the stopped single-well metering device based on the total flow rate collected by the total metering device and the flow rates of each single well collected by the other single-well metering devices.

[0024] The remote server performs statistical analysis on the historical single-well flow collected by each single-well metering device, analyzes the trend of each single-well flow, analyzes the range of each single-well flow in each time period, and analyzes the single-well flow that occurs most frequently in each time period. When multiple single-well metering devices stop operating, the remote server calculates the total single-well flow of the multiple stopped single-well metering devices based on the total flow collected by the total metering device and the single-well flow collected by other single-well metering devices. The remote server allocates the total single-well flow based on the statistical analysis of each historical single-well flow and estimates the single-well flow of each stopped single-well metering device. If a remote server analyzes and finds that the flow trend of a certain well has been stable over a historical period, the remote server divides each day into time periods and analyzes the flow range of each well in each time period during the historical period. Based on this, it initially analyzes the flow value range of the well where the metering equipment of the well that should stop operating in the current time period is located. Then, based on the flow of the well with the highest frequency in each time period, it is determined whether the flow of the well with the highest frequency is within the flow value range. If so, the flow of the well with the highest frequency is used as the allocated flow of that well. Finally, the allocated flow of each well is summarized. If the error between the summarized allocated flow and the total flow of the well is within the allowable range, it indicates that the allocation is reasonable and relatively accurate.

[0025] If the remote server analyzes that the traffic trend of a certain well fluctuates greatly during the historical period, it will analyze the average difference between the traffic fluctuation and the stable period for each time period of the day. Based on the average difference and the traffic of the well that appears most frequently in the same period, the allocated traffic of the well is estimated. Finally, the allocated traffic of each well is summarized. If the error between the summarized allocated traffic and the total traffic of the well is within the allowable range, it means that the allocation is reasonable and relatively accurate.

[0026] In this embodiment, in order to verify the accuracy of the information collected by the total metering device and the single-well metering devices when they are operating normally, the following method is adopted: When the total metering device is operating normally, the remote server calculates the total flow rate by summarizing the single-well flow rate information collected by each single-well metering device and compares it with the total flow rate collected by the total metering device to analyze the accuracy of the real-time information collected by the total metering device.

[0027] When it is necessary to detect whether the single-well flow rate collected by a single-well metering device is accurate, the local control module controls the single-well metering device to stop operating, controls the first valve to open, and controls the second valve to close. The remote server calculates the flow rate of the single well where the metering device to be tested is located based on the total flow rate collected and the single-well flow rates received from other single-well metering devices, and compares it with the single-well flow rate received before the device stopped operating. If they are the same or the error is within the allowable range, it is determined that the information collected by the single-well metering device is accurate.

[0028] Example 2

[0029] The difference between this embodiment and Embodiment 1 is that in this embodiment, the remote server also predicts future flow trends based on the historical single-well flow collected by each single-well metering device.

[0030] In this embodiment, when multiple single-well metering devices are out of service, the allocation of the total flow rate of each single well, i.e., the prediction of the flow rate of each single well, is based not only on historical flow analysis data but also on flow trend prediction data. The allocated flow rate of each single well is compared with the flow trend prediction data. If the difference between the two is within the allowable range, the accuracy of the allocated flow rate of the single well is considered to be relatively high. In this embodiment, to further verify the accuracy of the allocation, when the metering device of the out-of-service single well resumes operation, the collected flow data is compared with the flow trend prediction data. If the collected flow data matches the flow trend prediction data, the accuracy of the allocated flow rate is verified. The allocated flow rate is then allocated using historical analysis data and calibrated a second time using flow trend prediction data. Finally, after the single-well metering device resumes operation, the data is verified again, thereby ensuring the accuracy of the allocated flow rate through multiple means.

[0031] Those skilled in the art will understand that the above embodiments are specific examples of implementing the present invention, and in practical applications, various changes in form and detail may be made without departing from the spirit and scope of the present invention.

Claims

1. An intelligent diagnostic control system for metering equipment in oil and gas field production stations, characterized in that, The system includes multiple single-well metering devices, a total metering device, a communication module, a local control module, and a remote server. Each single-well metering device is connected at one end to an input branch pipe, which is connected to the discharge pipe of the corresponding oil and gas well. Each single-well metering device is connected at the other end to an output branch pipe, which is connected to a main pipe. The total metering device is mounted on the main pipe. The system also includes a single-well metering device field diagnostic module, a total metering device field diagnostic module, and an online calibration module. The single-well metering device field diagnostic module monitors the operating information of the single-well metering devices in real time, and the total metering device field diagnostic module monitors the operating information of the total metering device in real time. The operating information of both the individual well metering devices and the total metering device is transmitted to a remote server via a communication module. The remote server determines the current status of the individual well metering devices and the total metering device based on their respective operating information. The current status includes normal operation, calibration required, or fault. Based on the current status of the individual well metering devices and the total metering device, the remote server sends a control signal to the local control module. The local control module then controls the individual well metering device or the total metering device to stop operating based on the control signal, and controls the online calibration module to perform online calibration on the individual well metering device or the total metering device, or controls the individual well metering device or the total metering device to stop operating and then perform maintenance.

2. The system as described in claim 1, characterized in that, The main pipe is also equipped with gas-liquid separation metering and oil-water content measurement equipment.

3. The system as described in claim 1, characterized in that, The remote server stores a first flow range threshold and a second flow range threshold, respectively, and the range of the second flow range threshold is greater than that of the first flow range threshold. Based on this, the two flow range thresholds are used as the basis for judgment, so as to determine whether each single-well metering device is in normal operation, exceeds the first flow range threshold and needs calibration, or may have a fault and needs maintenance.

4. The system as described in claim 1, characterized in that, The calibration method of the online calibration module is as follows: The single-well flow rate and total flow rate collected by the single-well metering device and the total metering device are sent to the isolator, and then sent to the remote server through the isolator. During calibration, the online calibration module sends a standard current signal to the isolator and reads back the output signal of the isolator. If the output signal of the isolator is within the standard range, the calibration is completed.

5. The system as described in claim 1, characterized in that, When the total metering device stops operating, the remote server calculates the total flow by aggregating the flow information collected from each individual well metering device.

6. The system as described in claim 1, characterized in that, When a single-well metering device stops operating, the remote server calculates the flow rate of the stopped single-well metering device based on the total flow rate collected by the total metering device and the flow rates of each single well collected by the other single-well metering devices. The remote server performs statistical analysis on the historical single-well flow collected by each single-well metering device, analyzes the trend of each single-well flow, analyzes the range of each single-well flow in each time period, and analyzes the single-well flow that appears most frequently in each time period. When multiple single-well metering devices stop operating, the remote server calculates the total single-well flow of the multiple stopped single-well metering devices based on the total flow collected by the total metering device and the single-well flow collected by other single-well metering devices. The remote server allocates the total single-well flow based on the statistical analysis of each historical single-well flow and estimates the single-well flow of each stopped single-well metering device. If a remote server analyzes that the flow trend of a certain well has been stable over a historical period, the remote server divides the day into time periods and analyzes the flow range of each well in each time period during the historical period. Based on this, it preliminarily analyzes the flow value range of the well where the metering equipment of the well that should stop operating in the current time period is located. Then, based on the flow of the well with the highest frequency in each time period, it is determined whether the flow of the well with the highest frequency is within the flow value range. If so, the flow of the well with the highest frequency is used as the allocated flow of that well. Finally, the allocated flow of each well is summarized. If the error between the summarized allocated flow and the total flow of the well is within the allowable range, it indicates that the allocation is reasonable and relatively accurate. If the remote server analyzes that the traffic trend of a certain well fluctuates greatly during the historical period, it will analyze the average difference between the traffic fluctuation and the stable period for each time period of the day. Based on the average difference and the traffic of the well that appears most frequently in the same period, the allocated traffic of the well is estimated. Finally, the allocated traffic of each well is summarized. If the error between the summarized allocated traffic and the total traffic of the well is within the allowable range, it means that the allocation is reasonable and relatively accurate.

7. The system as described in claim 1, characterized in that, When the total metering device is operating normally, the remote server compares the total flow calculated by aggregating the flow information collected by each individual well metering device with the total flow collected by the total metering device to analyze the accuracy of the real-time information collected by the total metering device. When it is necessary to detect whether the single-well flow rate collected by a single-well metering device is accurate, the local control module controls the single-well metering device to stop operating, controls the first valve to open, and controls the second valve to close. The remote server calculates the flow rate of the single well where the metering device to be tested is located based on the total flow rate collected and the single-well flow rates received from other single-well metering devices, and compares it with the single-well flow rate received before the device stopped operating. If they are the same or the error is within the allowable range, it is determined that the information collected by the single-well metering device is accurate.

8. The system as described in claim 1, characterized in that, The remote server also predicts future flow trends based on historical single-well flow data collected from each single-well metering device.

9. The system as described in claim 1, characterized in that, It also includes an alarm module with multiple alarm prompt functions.

10. The system as described in claim 9, characterized in that, The alarm module provides the following alarm information: if calibration is required, the alarm module issues a calibration prompt; if a single well metering device or the total metering device malfunctions, the alarm module issues a metering device malfunction alarm; if the remote server cannot receive single well flow information and total flow information, the remote server sends a communication failure command to the local control module, and the local control module controls the alarm module to issue a communication failure alarm.

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