Mechanical study on the wellbore stability of horizontal wells in natural gas hydrate reservoirs

Yang, Li; Cheng, Yuanfang; Yan, Cheng; Song, Lifang; Liu, Hailong; Tian, Wenxi; Ren, Xu Dong

doi:10.1016/j.jngse.2020.103359

Cited by 44 publications

(26 citation statements)

References 39 publications

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“…The geological conditions affected all important aspects of offshore NGH resources, including formation, mitigation, reservation, exploitation, and exploration. 127,162,163,164,165,166,167 The geological conditions had both direct and indirect effects on sand production. As the direction effect, different geological conditions lead to various reservoir physical properties, such as reservoir stability and compaction, which further affects the sand production.…”

Section: Geologicalconditionandeffectmentioning

confidence: 99%

State‐of‐the‐art brief review on sanding problem of offshore natural gas hydrates sediments

Song

Xiong

et al. 2021

Energy Science & Engineering

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Section: Geologicalconditionandeffectmentioning

confidence: 99%

State‐of‐the‐art brief review on sanding problem of offshore natural gas hydrates sediments

Song

Xiong

et al. 2021

Energy Science & Engineering

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“…Nevertheless, some issues will probably occur during drilling or exploitation of natural gas hydrates offshore (Yan et al 2018;Song et al 2019;Yan et al 2020;Yang et al 2021;Li et al 2021a). Among them, as presented in Figure 1, hydrate dissociation around wellbore and borehole collapse caused by drilling uid disturbance during drilling operation is one issue that can't be ignored (Li et al 2020). As can be seen in Figure 1a, natural gas hydrates in the near-wellbore region are stable before or at the beginning of drilling operation, almost no hydrates dissociate (Li et al 2021b).…”

Section: Introductionmentioning

confidence: 99%

“…Generally speaking, disturbance of drilling uid on reservoir temperature and reservoir pressure persists throughout the drilling operation (Golmohammadi and Nakhaee 2015). As demonstrated in Figure 1b, changes in sediment temperature and sediment pressure in the near-wellbore region will cause hydrate dissociation (Song et (Li et al 2020). Borehole collapse will signi cantly affect the subsequent cementing operation, and the cementing quality will decline to a certain extent.…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation on hydrate dissociation in near-wellbore region caused by invasion of drilling fluid: ultrasonic measurement and analysis

Cheng

Ansari

et al. 2022

Environ Sci Pollut Res

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As we all know, development and utilization of clean energy is the only way for society to achieve sustainable development. Although natural gas hydrates is a new type of clean energy, uncontrollable hydrate dissociation and accompanying methane leakage in drilling operation threaten drilling safety and marine environment. However, dissociation range of natural gas hydrates around wellbore can't be reasonably and clearly determined in previous investigations, which may lead to the inaccurate estimation of borehole collapse and methane leakage. Then, the marine environment will be greatly damaged or affected. The purpose of the present work is to experimentally explore the dissociation characteristics of natural gas hydrates around wellbore in drilling operation, and analyze the in uence law and mechanism of various factors on hydrate dissociation. It is expected to provide reference for exploring effective engineering measures to avoid the uncontrolled hydrate dissociation, borehole collapse and accompanying methane leakage. The experimental results demonstrate that acoustic velocity of hydrate-bearing sediment can be accurately expressed as quadratic polynomial of hydrate saturation, which is the theoretical basis for determination of hydrate saturation in subsequent experiments. Owing to the fact that hydrate dissociation is an endothermic reaction, hydrate dissociation gradually slows down in experiment. Throughout the experiment, the maximum dissociation rate at the beginning of the experiment is 8.69 times that at the end of the experiment. In addition, sensitivity analysis found that the increase of stabilizer concentration in drilling uid can inhibit hydrate dissociation more than the increase in hydrate saturation. Hydrate dissociation was completely inhibited when the concentration of soybean lecithin exceeds 0.60wt%, but hydrate dissociation de nitely occurs in the near-wellbore region no matter what hydrate saturation is. In this way, based on the requirements of drilling safety and environment protection, hydrate dissociation and accompanying methane leakage can be controlled by designing and adjusting the stabilizer concentration in drilling uid.

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“…The prediction of wellbore temperature and pressure field has always been a major problem of common concern to scientists (Mirabbasi et al 2020), because it is related to the accurate construction of oil production technology (Li et al 2020;Jung et al 2020), the safety of pipe string (Guo et al 2021;Li et al 2021;Wang et al 2019a), the normal use of various downhole tools (Wang Sifan, Zhang Ankang, Hu Dongfeng 2021), the reliability of production process (Wang et al 2019b), and the wax and scale prevention of oil and gas wells affected by temperature and pressure (Wei et al 2017;Dalong et al 2021;Yang et al 2021;Wang 2019). Nowadays, in the daily production process of gas wells, the phase change of natural gas in the wellbore is becoming more and more common (Gholamzadeh et al 2020;).…”

Section: Introductionmentioning

confidence: 99%

Investigation and application of wellbore temperature and pressure field coupling with gas–liquid two-phase flowing

Zheng

Dou

et al. 2021

J Petrol Explor Prod Technol

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With the development of gas well exploitation, the calculation of wellbore with single-phase state affected by single factor cannot meet the actual needs of engineering. We need to consider the simulation calculation of complex wellbore environment under the coupling of multiphase and multiple factors, so as to better serve the petroleum industry. In view of the problem that the commonly used temperature and pressure model can only be used for single-phase state under complex well conditions, and the error is large. Combined with the wellbore heat transfer mechanism and the calculation method of pipe flow pressure drop gradient, this study analyzes the shortcomings of Ramey model and Hassan & Kabir model through transient analysis. Based on the equations of mass conservation, momentum conservation and energy conservation, and considering the interaction between fluid physical parameters and temperature and pressure, the wellbore pressure coupling model of water-bearing gas well is established, and the Newton Raphael iterative method is used for MATLAB programming. On this basis, the relationship between tubing diameter, gas production, gas–water ratio, and wellbore temperature field and pressure field in high water-bearing gas wells is discussed. The results show that the wellbore temperature pressure coupling model of high water-bearing gas well considering the coupling of gas–liquid two-phase flow wellbore temperature pressure field has higher accuracy than Ramey model and Hassan & Kabir model, and the minimum coefficients of variation of each model are 0.022, 0.037 and 0.042, respectively. Therefore, the model in this study is highly consistent with the field measured data. Therefore, the findings of this study are helpful to better calculate the wellbore temperature and pressure parameters under complex well conditions.

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Mechanical study on the wellbore stability of horizontal wells in natural gas hydrate reservoirs

Cited by 44 publications

References 39 publications

State‐of‐the‐art brief review on sanding problem of offshore natural gas hydrates sediments

State‐of‐the‐art brief review on sanding problem of offshore natural gas hydrates sediments

Experimental investigation on hydrate dissociation in near-wellbore region caused by invasion of drilling fluid: ultrasonic measurement and analysis

Investigation and application of wellbore temperature and pressure field coupling with gas–liquid two-phase flowing

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