An Integrated Approach for Downhole Leak Detection

Al-Hussain, Ali Musa; Hossain, Mohammed Kamal; Abdulraheem, Abdulazeez; Gajbhiye, Rahul

doi:10.2118/177996-ms

Cited by 9 publications

(1 citation statement)

References 28 publications

(21 reference statements)

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“…In general, downhole leaks are detected by measuring and analyzing the abnormal signals that are generated as leak flow moves through holes in the tubing, e.g., temperature, flow rate, and acoustic signals. Traditional logging methods, including flowmeter logging [4], temperature logging, ultrasonic logging [5], noise logging [6], and the integrated approach [7], can be used to measure abnormal signals by placing logging tools in the tubing. The abnormal signals in the tubing are measured and recorded by the sensors installed on the logging tools during lifting.…”

Section: Introductionmentioning

confidence: 99%

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

Liu

Fan

2018

Energies

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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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Section: Introductionmentioning

confidence: 99%

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

Liu

Fan

2018

Energies

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Application of downhole throttling technology to mitigate sustained casing pressure

Wang,

Qin,

Zhang

et al. 2024

J Petrol Explor Prod Technol

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Sustained casing pressure (SCP) and/or annular pressure build-up (APB) can pose severe threats to the safe operation of high-pressure, high-production gas wells, leading to premature well abandonment, unplanned workovers, significant production losses, and exorbitant detection costs. The techniques for addressing these issues broadly fall into two categories of rig-based and rig-less workovers. The rig-less workovers are the most cost-effective, outperforming surefooted rig-based workovers because there are many techniques for detecting downhole leaks, especially those utilizing rig-less data. As an established technique used elsewhere in the petroleum industry, downhole chokes have been proposed to mitigate SCP. However, some critical questions remain unanswered. For this reason and to facilitate field applicability, essential parameters, such as choke depth, are optimized in this work under various leaking circumstances in the tubing string. By using commercial software, the evolution of the annulus pressure with one single leak is analysed under the influences of certain parameters, such as leakage depth, casing pressure relief, production shifts, and initial gas column height in the tubing/casing annulus; then, the patterns of fluid exchange between the tubing and casing string and the annular pressure rise are investigated for two successive leaks. Finally, based on the resulting insights, the adaptability levels of downhole throttling technology for mitigating SCP are investigated under various scenarios with either single or double leaks. The results show that the key to success is to land below the leak for a single leak and below the lower leak for double leaks. The conclusions provide a low-cost, rigid measure for abating SCP.

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