Sensitivity analysis of hydrate dissociation front conditioned to depressurization and wellbore heating

Zheng, Ruyi; Li, Shuxia; Li, Xiaoli

doi:10.1016/j.marpetgeo.2018.01.010

Cited by 70 publications

(21 citation statements)

References 33 publications

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“…Although many hydrochemical models and numerical codes have been developed and implemented to study CH 4 hydrate production as summarized by White et al [58], only a few of these are capable of reproducing hydrate formation by the "excess-gas" and "excess-water" methods. Among those numerical implementations, HydrateResSim (HRS) [59,60] is the only available open-source and open-access code, describing both equilibrium and kinetic models of hydrate formation, and only a few studies [61,62] have made use of it recently.…”

Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Hydrate Formation in the LArge-Scale Reservoir Simulator (LARS)

Spangenberg

Schicks

et al. 2022

Energies

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The LArge-scale Reservoir Simulator (LARS) has been previously developed to study hydrate dissociation in hydrate-bearing systems under in-situ conditions. In the present study, a numerical framework of equations of state describing hydrate formation at equilibrium conditions has been elaborated and integrated with a numerical flow and transport simulator to investigate a multi-stage hydrate formation experiment undertaken in LARS. A verification of the implemented modeling framework has been carried out by benchmarking it against another established numerical code. Three-dimensional (3D) model calibration has been performed based on laboratory data available from temperature sensors, fluid sampling, and electrical resistivity tomography. The simulation results demonstrate that temperature profiles, spatial hydrate distribution, and bulk hydrate saturation are consistent with the observations. Furthermore, our numerical framework can be applied to calibrate geophysical measurements, optimize post-processing workflows for monitoring data, improve the design of hydrate formation experiments, and investigate the temporal evolution of sub-permafrost methane hydrate reservoirs.

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Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Hydrate Formation in the LArge-Scale Reservoir Simulator (LARS)

Spangenberg

Schicks

et al. 2022

Energies

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“…This method can also significantly improve the energy ratio compared with the thermal stimulation method alone. Current studies determined that depressurisation combined with hot water injection (D + T iw ) significantly increased the NGH decomposition rate and CH 4 production rate. ,− However, in a low-permeability NGH reservoir, the poor depressurisation effect and hot water flow capacity severely limit the production capacity of D + T iw. , …”

Section: Introductionmentioning

confidence: 99%

Research on the Influence of Injection–Production Parameters on Challenging Natural Gas Hydrate Exploitation Using Depressurization Combined with Thermal Injection Stimulated by Hydraulic Fracturing

et al. 2021

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The development of low-permeability hydrate reservoirs is facing serious problems. Our previous studies determined that depressurization combined with hot water injection stimulated by hydraulic fracturing (D + Tiw + HF) development mode has an excellent production potential in low-permeability hydrate reservoirs. Based on these, this study further explored the influences of injection–production parameters including injection temperature (T i), injection pressure (P i), and production pressure (P p) on D + Tiw + HF through single-factor and multivariate sensitivity analysis. Results show that the influence of T i, P i, and P p on D + Tiw + HF was divided into two opposite stages by the water breakthrough of production wells (t wb). The hydrate decomposition rate and CH4 production rate increase linearly with the increase in T i and P i and decrease in P p before t wb; however, they decrease gradually with the increase in T i and P i and decrease in P p after t wb. The sensitivity ranges of cumulative CH4 production (V P) to P p, T i, and P i are (3, 4.5), (0, 1.5), and (0, 1) in the first year and (1, 5), (0.5, 3), and (1, 2) in the fifth year, respectively. The sensitivity ranges of the energy ratio (ER) to P p, T i, and P i are (−2, −1), (−6, 0), and (−2.5, −1.5) in the first year and (−1.5, −1), (−7, 0), and (−2, 1) in the fifth year, respectively. This determines that V P is most sensitive to Pp , and the ER is most sensitive to T i. Furthermore, the ER is more sensitive to smaller T i. The V P is more sensitive to smaller P p in the early development stage (1 year, before t wb), while it is more sensitive to lager P p in the later development stage (5 years, after t wb). As a result, an as low as possible P p, low T i, and higher P i is suggested in the early development stage, while low T i and higher P i are suggested in the later development stage, and too small P p is unnecessary.

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“…Tang et al [19] obtained an estimate of the order of intrinsic MH dissociation constant from their experimental data of gas production from hydrate-bearing cores, but could not reconcile the discrepancies in the response of T between simulation and observation (possibly because of the assumption of uniform SH distribution). Recently, Zheng et al [20,21] investigated the effects of boundary conditions and petrophysical properties on hydrate dissociation using 1D domains with meshes that were too coarse (Δx = 1m) to capture the intense chemical and thermophysical localized processes associated with hydrate dissociation. They determined that the location of the dissociation front over time could be described by a power function.…”

Section: Introductionmentioning

confidence: 99%

On the importance of phase saturation heterogeneity in the analysis of laboratory studies of hydrate dissociation

2019

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Methane hydrates (MHs) have been considered as the future source of energy because of its vast resource volume and high energy density. Energy recovery from MH-bearing sediments has attracted intensifying research activities. Fundamentally, heat transfer, fluid flow through porous media, and the kinetics of hydrate reaction are the three key processes controlling the behavior of MH dissociation and the associated fluid production. Earlier studies have suggested that heterogeneous spatial distribution of SH is inevitable in MHbearing samples synthesized in laboratory. In this paper, we extend our study to analyze numerically the simulation results from the two realizations of the samples (homogeneous and heterogeneous) to identify differences in the fluid production and to determine if they are sufficiently different. Additionally, we conduct a sensitivity analysis and a statistical analysis on the key transport and kinetic rate parameters that could affect hydrate dissociation and fluid production in the context of a heterogeneous hydrate-bearing sample, in an effort to provide insights that could lead to improved designs for laboratory experiments and (possibly) field applications. Our results suggest that the approximation of an artificial hydrate-bearing core with heterogeneous phase saturations by an assumption of uniform phase saturation distributions results in practically similar fluid production profile except for the very early stage with maximum 20.0% deviation in the water production. From the sensitivity and statistical analysis, we determine that gas production depends strongly on the kinetic rate constant, Kd 0 and the composite thermal conductivity of the hydrate-bearing sediments, λθ; while, water production is very sensitive to Kd 0 and the absolute permeability of the sandy medium, k. Understanding the effect of phase 2 heterogeneity and the relative importance of key parameters on the production behavior of hydrate-bearing sediments could provide basis for novel production technologies that lead to enhanced gas production and energy efficiency in the energy recovery process.

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Sensitivity analysis of hydrate dissociation front conditioned to depressurization and wellbore heating

Cited by 70 publications

References 33 publications

Numerical Simulation of Hydrate Formation in the LArge-Scale Reservoir Simulator (LARS)

Numerical Simulation of Hydrate Formation in the LArge-Scale Reservoir Simulator (LARS)

Research on the Influence of Injection–Production Parameters on Challenging Natural Gas Hydrate Exploitation Using Depressurization Combined with Thermal Injection Stimulated by Hydraulic Fracturing

On the importance of phase saturation heterogeneity in the analysis of laboratory studies of hydrate dissociation

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