Prediction of the mechanical response of hydrate‐bearing sands

Pinkert, Shmulik; Grozic, J. L. H.

doi:10.1002/2013jb010920

Cited by 65 publications

(39 citation statements)

References 16 publications

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“…Hydrate saturation and pore habit‐dependent small‐strain stiffness of hydrate‐bearing sediments have been investigated experimentally (Priest et al, , ; Yun et al, ), numerically (Guerin & Goldberg, , ; Pinkert & Grozi, ; Marín‐Moreno et al, ), and analytically (Chand et al, ; Helgerud et al, ; Lee, ; Lee et al, ; Uchida et al, ). However, the impacts of hydrate on the shear strength and deformation of hydrate‐bearing sediments, particularly at large strain levels, remain elusive.…”

Section: Introductionmentioning

confidence: 99%

Strength Estimation for Hydrate‐Bearing Sediments From Direct Shear Tests of Hydrate‐Bearing Sand and Silt

Liu

Dai

Ning

et al. 2018

Geophysical Research Letters

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Safe and economic methane gas production, as well as the replacement of methane while sequestering carbon in natural hydrate deposits, requires enhanced geomechanical understanding of the strength and volume responses of hydrate‐bearing sediments during shear. This study employs a custom‐made apparatus to investigate the mechanical and volumetric behaviors of carbon dioxide hydrate‐bearing sediments subjected to direct shear. The results show that both peak and residual strengths increase with increased hydrate saturation and vertical stress. Hydrate contributes mainly the cohesion and dilatancy constraint to the peak strength of hydrate‐bearing sediments. The postpeak strength reduction is more evident and brittle in specimens with higher hydrate saturation and under lower stress. Significant strength reduction after shear failure is expected in silty sediments with high hydrate saturation Sh ≥ 0.65. Hydrate contribution to the residual strength is mainly by increasing cohesion at low hydrate saturation and friction at high hydrate saturation. Stress state and hydrate saturation are dominating both the stiffness and the strength of hydrate‐bearing sediments; thus, a wave velocity‐based peak strength prediction model is proposed and validated, which allows for precise estimation of the shear strength of hydrate‐bearing sediments through acoustic logging data. This method is advantageous to geomechanical simulators, particularly when the experimental strength data of natural samples are not available.

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Section: Introductionmentioning

confidence: 99%

Strength Estimation for Hydrate‐Bearing Sediments From Direct Shear Tests of Hydrate‐Bearing Sand and Silt

Liu

Dai

Ning

et al. 2018

Geophysical Research Letters

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“…Based on these experimental data, various constitutive models of HBS have been proposed and improved (Pinkert and Grozic, 2014;Lin et al, 2015;Pinkert et al, 2015;Sun et al, 2015;Shen et al, 2016;Uchida et al, 2016). Developing multi-field coupling numerical simulators with different constitutive models has been treated as an essential for analyzing mechanical responses of hydrate-bearing reservoirs during depressurization.…”

Section: Introductionmentioning

confidence: 99%

Numerical simulations for analyzing deformation characteristics of hydrate-bearing sediments during depressurization

Liu

Zhang

et al. 2017

Adv. Geo-Energ. Res.

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Natural gas hydrates have been treated as a potential energy resource for decades. Understanding geomechanical properties of hydrate-bearing porous media is an essential to protect the safety of individuals and devices during hydrate production. In this work, a numerical simulator named GrapeFloater is developed to study the deformation behavior of hydrate-bearing porous media during depressurization, and the numerical simulator couples multiple processes such as conductive-convective heat transfer, two-phase fluid flow, intrinsic kinetics of hydrate dissociation, and deformation of solid skeleton. Then, a depressurization experiment is carried out to validate the numerical simulator. A parameter sensitivity analysis is performed to discuss the deformation behavior of hydrate-bearing porous media as well as its effect on production responses. Conclusions are drawn as follows: the numerical simulator named GrapeFloater predicts the experimental results well; the modulus of hydrate-bearing porous media has an obvious effect on production responses; final deformation increases with decreasing outlet pressure; both the depressurization and the modulus decrease during hydrate dissociation contribute to the deformation of hydrate-bearing porous media.

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“…The calculation method in the plastic strain iteration is as shown in Equation (12). The calculation method in the plastic strain iteration is as shown in Equation (12).…”

Section: Hydrate Reservoir Creep Modelmentioning

confidence: 99%

“…[6][7][8][9] Scholars from various countries have carried out a lot of research on the mechanical properties of the formation with hydrate, and found that hydrate reservoirs have low strength and strong creep properties. 12 Due to the disturbance of drilling engineering, stress concentration will occur near the wellbore. For different hydrate reservoirs, the hydrate saturation would be different, affecting its creep properties.…”

Section: Introductionmentioning

confidence: 99%

Wellbore shrinkage during drilling in methane hydrate reservoirs

Yan

Yang

Yan³

et al. 2019

Energy Science & Engineering

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Methane hydrates as a clean and abundant energy source, have attracted the attention of the world. However, the instability of hydrate reservoirs makes it difficult to drill production wells. After drilling, the creep properties of hydrate reservoir would cause wellbore shrinkage, which will affect the drilling safety. This study is to analysis law of wellbore shrinkage after a hydrate well drilled. The results demonstrate that wellbore shrinkage mainly results from plastic deformation and creep deformation. The largest and smallest values are separately found in the directions of the maximum and minimum horizontal in‐situ stress. With the increase of initial in‐situ stress ratio, wellbore shrinkage linearly rise. Under the condition of low horizontal in‐situ stress ratio, wellbore shrinkage is mainly determined by creep deformation. Under the condition of high horizontal in‐situ stress ratio, wellbore shrinkage commonly depends on plastic deformation and creep deformation. With deepening methane hydrate reservoirs, wellbore shrinkage shows a nonlinear increase. For formations with higher hydrate saturation, larger wellbore shrinkage would occur. The research results can provide a theoretical basis for the selection of drilling method while drilling in hydrate formations.

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Prediction of the mechanical response of hydrate‐bearing sands

Cited by 65 publications

References 16 publications

Strength Estimation for Hydrate‐Bearing Sediments From Direct Shear Tests of Hydrate‐Bearing Sand and Silt

Strength Estimation for Hydrate‐Bearing Sediments From Direct Shear Tests of Hydrate‐Bearing Sand and Silt

Numerical simulations for analyzing deformation characteristics of hydrate-bearing sediments during depressurization

Wellbore shrinkage during drilling in methane hydrate reservoirs

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