A Novel Acoustic Liquid Level Determination Method for Coal Seam Gas Wells Based on Autocorrelation Analysis

Zhang, Ximing; Fan, Jun; Wu, Shengnan; Liu, Di

doi:10.3390/en10121961

Cited by 10 publications

(4 citation statements)

References 44 publications

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“…Based on (11) estimations can now be completed for real pipelines whilst considering the attenuation constants as in Table 2. For example, for a stimulated power of 60 dBm (or 1 kW), theoretical depths for liquid level determinations are about 250 meters.…”

Section: Budget Analysismentioning

confidence: 99%

A Microwave Liquid Level Determination Method for Oil and Gas Pipelines

Kossenas

Podilchak

Beveridge³

2022

IEEE Access

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The modeling and design of a complete wireless liquid level determination system within a metallic pipeline is examined. Applications include the oil and gas industry, and propagation within other enclosed environments like tunnels, mines, and airplanes. For the oil and gas well scenario, the liquid level determination is achieved by measuring the delay between the original and the reflected signal by a liquid that could be positioned at the bottom of an oil well. In the design of the proposed system, the propagating mode was selected to be a superposition of the TE 21 and the TE 31 modes of the overmoded guide as standard pipeline dimensions from the oil and gas industry were employed. The wave velocity for the adopted signal within the guide was also defined and verified by theory, full wave simulations, and measurements. In particular, the excited signals were Gaussian and rectangular pulses. A specific link budget equation was also developed for the 2.4 GHz microwave system and measured successfully using a 2 meter carbon steel pipeline. Based on this link budget equation, which was supported by lab measurements, the maximum depth that can be achieved with the proposed system is 250 meters, and when the stimulated power is 1 kW; this range is mainly defined by the attenuation due to metal along the length of the pipe. Regardless of these factors and to the best knowledge of the authors, no similar microwave liquid level determination system has been developed previously with supporting theory, full-wave simulations, and measurements for propagation within industry standard oil and gas wells.

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Section: Budget Analysismentioning

confidence: 99%

A Microwave Liquid Level Determination Method for Oil and Gas Pipelines

Kossenas

Podilchak

Beveridge³

2022

IEEE Access

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“…A time delay exists when Figure 1. Schematic of the wellbore structure [24] and the detection principle of tubing leakage acoustic waves. Acoustic waves will be generated by tubing leakage and then propagated in the wellbore.…”

Section: Principlesmentioning

confidence: 99%

“…The annulus pressure can be calculated by using the integration method [24], which can be expressed as dp a dH = gρ g sin θ…”

Section: Pressure Distribution In the Annulusmentioning

confidence: 99%

Acoustic Wave-Based Method of Locating Tubing Leakage for Offshore Gas Wells

Liu

Fan

2018

Energies

Self Cite

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This paper presents a novel acoustic wave-based method for the detection of leakage in downhole tubing of offshore gas wells. The localization model is developed on the basis of analyzing the propagation model of leakage acoustic waves and the critical factors in localization. The proposed method is validated using experimental laboratory investigations that are conducted to locate tubing leakage by setting five holes at different positions on the tubing wall. A detection system is developed for the leakage acoustic waves in the tubing-casing annulus, where one acoustic sensor is installed at the annulus top. Laboratory experimental results show that the depth of downhole leakage can be effectively located by using the proposed localization model. The localization errors are kept at a very low level, and are mainly generated from extracting the characteristic time and calculating annular acoustic velocity. A case study focusing on an offshore gas well is presented to illustrate the feasibility of the proposed method, and to demonstrate that the proposed model can locate the liquid level and leakage points under field conditions. The test can be performed without interrupting the production of gas wells.Energies 2018, 11, 3454 2 of 21 by each sensor. The instrument does not move in the tubing. The test precision is relatively improved by the distributed sensor array. However, the results greatly rely on the reliability of the instrument and the efficiency of signal processing. The current implementation of logging and distributed sensor arrays requires the instrument to be placed in the tubing, and the well needs to be shut down during testing. This process usually entails large costs and risk. Therefore, detecting tubing leakage without interrupting well production is necessary.Tubing leakage will cause pressure changes in the tubing-casing annulus. Zhu et al. have introduced a calculation model of tubing leak depth based on the pressure balance principle when investigating the prediction model of annulus pressure in the CO 2 injection well [11]. Wu et al. further studied this principle and extended it to production gas wells [12,13]. The Bayesian inference is introduced to handle the uncertainties in leakage location forecasting that are caused by variations in reservoir conditions and measurement errors. Meanwhile, an annulus pressure monitoring system is developed to assist diagnosis. This method is theoretically feasible, and does not affect the well production. However, the accuracy of results greatly relies on the wellbore fluid calculation and production status. The locating process needs the production and annulus pressure to be kept stable. This method also requires accurate liquid level information in the annulus, and is not suitable for a well that leaks at an excessive inclination or horizontal sections. Zhang et al. presented a method based on the application of a He tracer [14]. The tracers are injected from the annulus and detected at the choke. The leak depth is calculated by using the flowing tim...

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“…In 2017, Zhang et al proposed a self-correlation analysis-based acoustic wave processing method for oil well dynamic liquid levels. This method is only applicable to shallow wells with multiple liquid level echoes, and it is not suitable for deep wells with weak acoustic signals [ 13 ].…”

Section: Introductionmentioning

confidence: 99%

Robust Intelligent Monitoring and Measurement System toward Downhole Dynamic Liquid Level

Liu,

Fan,

Liu

et al. 2024

Sensors

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Dynamic liquid level monitoring and measurement in oil wells is essential in ensuring the safe and efficient operation of oil extraction machinery and formulating rational extraction policies that enhance the productivity of oilfields. This paper presents an intelligent infrasound-based measurement method for oil wells’ dynamic liquid levels; it is designed to address the challenges of conventional measurement methods, including high costs, low precision, low robustness and inadequate real-time performance. Firstly, a novel noise reduction algorithm is introduced to effectively mitigate both periodic and stochastic noise, thereby significantly improving the accuracy of dynamic liquid level detection. Additionally, leveraging the PyQT framework, a software platform for real-time dynamic liquid level monitoring is engineered, capable of generating liquid level profiles, computing the sound velocity and liquid depth and visualizing the monitoring data. To bolster the data storage and analytical capabilities, the system incorporates an around-the-clock unattended monitoring approach, utilizing Internet of Things (IoT) technology to facilitate the transmission of the collected dynamic liquid level data and computed results to the oilfield’s central data repository via LoRa and 4G communication modules. Field trials on dynamic liquid level monitoring and measurement in oil wells demonstrate a measurement range of 600 m to 3000 m, with consistent and reliable results, fulfilling the requirements for oil well dynamic liquid level monitoring and measurement. This innovative system offers a new perspective and methodology for the computation and surveillance of dynamic liquid level depths.

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A Novel Acoustic Liquid Level Determination Method for Coal Seam Gas Wells Based on Autocorrelation Analysis

Cited by 10 publications

References 44 publications

A Microwave Liquid Level Determination Method for Oil and Gas Pipelines

A Microwave Liquid Level Determination Method for Oil and Gas Pipelines

Acoustic Wave-Based Method of Locating Tubing Leakage for Offshore Gas Wells

Robust Intelligent Monitoring and Measurement System toward Downhole Dynamic Liquid Level

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