Real-time monitoring method for liquid accumulation amount in oil pipe of natural gas well and related device

By monitoring the natural gas wellhead parameters in real time and calculating the internal fluid accumulation volume of the gas well, the problem of inaccurate judgment of the fluid accumulation status of the gas well and real-time monitoring of dynamic changes in the existing technology is solved, and efficient and stable production of the gas well is achieved.

CN120291858APending Publication Date: 2025-07-11XI AN JIAOTONG UNIV
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Patent Information

Application Number
CN202510458151.X
Authority / Receiving Office
CN · China
Patent Type
Applications(China)
Current Assignee / Owner
Filing Date
2025-04-14
Publication Date
2025-07-11

AI Technical Summary

Technical Problem

The prior art cannot accurately determine the fluid accumulation status in the gas well, and cannot monitor dynamic changes in real time, resulting in gas well production cuts or suspensions.

Method used

By collecting the instantaneous wellhead oil pressure, temperature, gas production and water production of natural gas wellhead in real time, calculate the water-gas ratio of the gas well, the true density of the natural gas gas phase, kinematic viscosity, flow rate and Reynolds number, determine the dimensionless liquid accumulation inside the oil pipe, and finally obtain the actual liquid phase content.

Benefits of technology

Real-time and quantitative monitoring of the amount of fluid accumulation in the oil pipe of the gas well is achieved, and the fluid accumulation problem can be discovered in a timely manner, avoid gas well production reduction or suspension, and improve gas well mining efficiency.

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Abstract

The invention belongs to a monitoring method, and provides a real-time monitoring method for the amount of liquid accumulated in an oil pipe of a natural gas well and a related device aiming at the technical problems that whether accurate prediction is carried out or not cannot be judged and dynamic changes cannot be monitored in real time in two methods for judging the state of the liquid accumulated in the gas well at present. The method comprises the following steps: acquiring instantaneous wellhead oil pressure, instantaneous wellhead temperature, instantaneous gas production rate and instantaneous water production rate of a natural gas wellhead in real time, and then respectively determining a gas well water-gas ratio, natural gas phase real density, natural gas real kinematic viscosity, natural gas phase real flow rate, natural gas phase Reynolds number and non-dimensional liquid accumulation amount in an oil pipe; and obtaining the actual liquid phase content according to the non-dimensional liquid accumulation amount in the oil pipe, the diameter of the oil pipe and the depth of the oil pipe. Production structure parameters such as instantaneous gas production, instantaneous water production, instantaneous wellhead oil pressure, instantaneous wellhead temperature and the like which are easy to obtain on site can be directly utilized to obtain a liquid accumulation amount evolution dynamic curve of the gas well in the continuous production process.
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