Geomechanics involved in gas hydrate recovery

Liu, Zhiqiang; Lü, Yuling; Cheng, Jiuhui; Han, Qiang; Hu, Zunjing; Wang, Linlin

doi:10.1016/j.cjche.2019.02.015

Cited by 18 publications

(12 citation statements)

References 86 publications

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“…Different from these curves above, there is an excellent possibility of making the P – T trajectory be A–G via an in-situ heat supply assisted DP method due to a long time of the continuous process of heat supplement (indirect improvement of sensible heat in HBS), and this improvement effect is better in HBS with a larger porosity, indicating that the thermal field disturbance in HBS and surrounding formation will be reduced during the NGH dissociation. Evidently, given the THMC coupling relationship during production, a minor thermal field disturbance will exert a small linkage effect for the hydraulic–mechanical–chemical fields, which is more conducive to efficient hydrate exploitation and geological risk control. , Also, notice that path A–G is only an ideal situation, and the actual path is bound to fluctuate.…”

Section: Plan Of Enhanced Gas Production From Hbsmentioning

confidence: 99%

“…Evidently, given the THMC coupling relationship during production, a minor thermal field disturbance will exert a small linkage effect for the hydraulic−mechanical−chemical fields, which is more conducive to efficient hydrate exploitation and geological risk control. 351,352 Also, notice that path A−G is only an ideal situation, and the actual path is bound to fluctuate. 5.2.2.…”

Section: Field Tests Of Hydrate Exploitationmentioning

confidence: 99%

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Recent Advances in Methods of Gas Recovery from Hydrate-Bearing Sediments: A Review

et al. 2022

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Safe, efficient, and economical gas recovery from hydrate-bearing sediments (HBS) is a severe issue that determines if natural gas hydrate (NGH), as an alternative energy in the future as fossil fuels approach depletion, is applied. Researchers worldwide are committed to developing a safe, efficient, and economical method of gas recovery from HBS. However, until now, most methods are still being validated and not have not been identified to exploit NGH commercially. Therefore, it is appropriate and significant to discuss researchers’ achievements to exploit NGH and summarize their potential benefits and challenges. This paper introduces nearly all the conventional and latest NGH exploitation methods and reviews field trials’ development characteristics. On the basis of laboratory experiments and field trials, key challenges restricting safe and efficient NGH development, and the existing research gaps reflecting these challenges, are also presented from the gas production, security, and economic aspects. The unfavorable situation mainly comprises the insufficient sensible heat, extremely low thermal conductivity, and ultralow permeability of HBS, lower gas production rate and its intense fluctuations, higher water-to-gas ratio (WGR), geological deformation, and subsidence of HBS attributed to excessive sand production, driving the consideration of some possible solutions. Given this, a new method for enhanced gas production from HBS based on the combination of depressurization (DP) and an in-situ heat generation method is proposed. Benefiting from multiple theoretical enhancement mechanisms such as replenishing energy to HBS with in-situ heat generation powders, cementing and strengthening the HBS skeleton, improving the gas permeability in HBS, decreasing the WGR based on blocking water, and removing gas characteristics of hydration products, this method could be expected to achieve promising long-term performance of gas production, which will be theoretically and practically significant to study commercial gas production.

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Section: Plan Of Enhanced Gas Production From Hbsmentioning

confidence: 99%

Section: Field Tests Of Hydrate Exploitationmentioning

confidence: 99%

Recent Advances in Methods of Gas Recovery from Hydrate-Bearing Sediments: A Review

et al. 2022

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“…Moreover, methane production is generally accompanied with sand migration, which impact on both borehole mechanical stability and fluids flow. Sand production is considered as one of the major limitations for the commercial exploitation of gas hydrate (e.g., [11,12]). It is then apparent that the profound perturbations in the sediment condition and the multiphysics nature of this problem, with the strong couplings between the different thermo-hydromechanical and chemical (THMC) phenomena that control the sediment behavior require the development of advanced and robust models.…”

Section: Introductionmentioning

confidence: 99%

A Geomechanical Model for Gas Hydrate Bearing Sediments Incorporating High Dilatancy, Temperature, and Rate Effects

et al. 2022

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The geomechanical behavior of methane hydrate bearing sediments (MHBS) is influenced by many factors, including temperature, fluid pressure, hydrate saturation, stress level, and strain rate. The paper presents a visco-elastoplastic constitutive model for MHBS based on an elastoplastic model that incorporates the effect of hydrate saturation, stress history, and hydrate morphology on hydrate sediment response. The upgraded model is able to account for additional critical features of MHBS behavior, such as, high-dilatancy, temperature, and rate effects. The main components and the mathematical formulation of the new constitutive model are described in detail. The upgraded model is validated using published triaxial tests involving MHBS. The model agrees overly well with the experimental observations and is able to capture the main features associated with the behavior of MHBS.

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“…NGH is a clean and initial‐developed solid energy, which is composed under high‐pressure and low‐temperature conditions of water and natural gas including methane, ethane, propane, and carbon dioxide 8 . The total amount of carbon reserved in NGH is more than twice the total amount of fossil fuel worldwide 9 . The estimated NGH reserves, which are around 2.1 × 10 16 m 3 , are capable to support normal human activities for 1000 years 10 .…”

Section: Introductionmentioning

confidence: 99%

Heat transfer study in the exploitation of argillaceous‐silt natural gas hydrate reservoirs

Jiang

Song

Liu

et al. 2022

Energy Science & Engineering

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The paper investigates the heat transfer in the exploitation of offshore argillaceous-silt natural gas hydrate reservoirs considering sand control. The temperature prediction model is established in this investigation. The coupled pressure-temperature model of the flowing fluid inside the wellbore is also presented. The sand control for argillaceous-silt natural gas hydrate reservoirs mainly brings two effects into the temperature and pressure profiles simulation, including the moderate sand control and the Joule-Thompson effect. The moderate sand control is reflected by the volume and particle size of produced sand into the wellbore in the mathematical derivation. The Joule-Thompson is considered in the model due to the small diameter of sand control screens. The experiment is designed to measure the pressure drop caused by various mesh diameters of sand control screens. Subsequently, the regression relationship between the pressure drop and the mesh diameter is concluded to calculate the temperature change at the sand control screen. The simulation of heat transfer helps to analyze secondary hydrate formation risk in the wellbore. The proposed model identifies the high-risk location of the secondary hydrate formation. The sand control effect and well geometry effect are discussed quantitatively. The strict sand control in the argillaceous-silt natural gas hydrate (NGH) sediment exploitation reduces the risk of secondary hydrate formation significantly; however, it also has a negative effect on natural gas production. To balance the sand control and the prevention of secondary hydrate formation risk, it is suggested to install the heating electrode in the high-risk location to ensure flow safety with acceptable sand control precision. The heat provided by heat electrodes is calculated by the model presented in this paper. The model can be used to determine the proper arrangement of heat electrodes. The paper also describes the secondary hydrate formation by adjusting the well geometry. The formation depth of the NGH reservoir and the sea interval should be considered in the risk analysis of

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Geomechanics involved in gas hydrate recovery

Cited by 18 publications

References 86 publications

Recent Advances in Methods of Gas Recovery from Hydrate-Bearing Sediments: A Review

Recent Advances in Methods of Gas Recovery from Hydrate-Bearing Sediments: A Review

A Geomechanical Model for Gas Hydrate Bearing Sediments Incorporating High Dilatancy, Temperature, and Rate Effects

Heat transfer study in the exploitation of argillaceous‐silt natural gas hydrate reservoirs

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