A review: Enhanced recovery of natural gas hydrate reservoirs

Li, Fengguang; Yuan, Qing; Li, Tianduo; Li, Zhi; Sun, Chang‐Yu; Chen, Guangjin

doi:10.1016/j.cjche.2018.11.007

Cited by 68 publications

(41 citation statements)

References 103 publications

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“…Stanwix et al [31] reviewed pure CO 2 replacement experiments, reporting up to 50% CH 4 recovery. There are many hydrate-focused review studies which also provide excellent summaries of CH 4 -CO 2 replacement in hydrates [32][33][34][35][36][37][38][39][40][41][42][43].…”

Section: Introductionmentioning

confidence: 99%

Enhanced CH4-CO2 Hydrate Swapping in the Presence of Low Dosage Methanol

et al. 2020

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CO2-rich gas injection into natural gas hydrate reservoirs is proposed as a carbon-neutral, novel technique to store CO2 while simultaneously producing CH4 gas from methane hydrate deposits without disturbing geological settings. This method is limited by the mass transport barrier created by hydrate film formation at the liquid–gas interface. The very low gas diffusivity through hydrate film formed at this interface causes low CO2 availability at the gas–hydrate interface, thus lowering the recovery and replacement efficiency during CH4-CO2 exchange. In a first-of-its-kind study, we have demonstrate the successful application of low dosage methanol to enhance gas storage and recovery and compare it with water and other surface-active kinetic promoters including SDS and L-methionine. Our study shows 40–80% CH4 recovery, 83–93% CO2 storage and 3–10% CH4-CO2 replacement efficiency in the presence of 5 wt% methanol, and further improvement in the swapping process due to a change in temperature from 1–4 °C is observed. We also discuss the influence of initial water saturation (30–66%), hydrate morphology (grain-coating and pore-filling) and hydrate surface area on the CH4-CO2 hydrate swapping. Very distinctive behavior in methane recovery caused by initial water saturation (above and below Swi = 0.35) and hydrate morphology is also discussed. Improved CO2 storage and methane recovery in the presence of methanol is attributed to its dual role as anti-agglomerate and thermodynamic driving force enhancer between CH4-CO2 hydrate phase boundaries when methanol is used at a low concentration (5 wt%). The findings of this study can be useful in exploring the usage of low dosage, bio-friendly, anti-agglomerate and hydrate inhibition compounds in improving CH4 recovery and storing CO2 in hydrate reservoirs without disturbing geological formation. To the best of the authors’ knowledge, this is the first experimental study to explore the novel application of an anti-agglomerate and hydrate inhibitor in low dosage to address the CO2 hydrate mass transfer barrier created at the gas–liquid interface to enhance CH4-CO2 hydrate exchange. Our study also highlights the importance of prior information about methane hydrate reservoirs, such as residual water saturation, degree of hydrate saturation and hydrate morphology, before applying the CH4-CO2 hydrate swapping technique.

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Section: Introductionmentioning

confidence: 99%

Enhanced CH4-CO2 Hydrate Swapping in the Presence of Low Dosage Methanol

et al. 2020

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“…10 Therefore, CO 2 is suggested to displace CH 4 from hydrate phase, releasing CH 4 and capturing CO 2 in the hydrate bearing sediments, which is expected to impact on both the sustainability of energy system and the global climate change. [11][12][13] The gas exchange concept for natural gas production has been conrmed viable technically. In 2011 and 2012, the eld test conducted at the Alaska North Slope tried to replace CH 4 with a gas mixture of 23 mol% CO 2 and 77 mol% N 2 from hydrate reservoir and found that a total of 24410 m 3 of CH 4 was recovered by sequestrating 2247 m 3 of N 2 -CO 2 mixtures successfully within 48 days.…”

Section: Introductionmentioning

confidence: 99%

Molecular insight into carbon dioxide hydrate formation from saline solution

2021

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“…With the rapid growth of the global economy, the conventional oil and gas resources with decreasing production cannot meet the need for energy. Unconventional energy resources such as shale gas, shale oil, gas hydrate, and dry hot rock geothermal energy are quite abundant, and their economically and technically feasible exploitation is an effective solution to the problem of future energy shortages [1][2][3][4]. However, extremely tight pore structure and ultra-low permeability for the unconventional reservoir rocks restrict the flow of energy and efficient production [5,6].…”

Section: Introductionmentioning

confidence: 99%

Numerical Investigation of Injection-Induced Fracture Propagation in Brittle Rocks with Two Injection Wells by a Modified Fluid-Mechanical Coupling Model

et al. 2020

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Hydraulic fracturing is a key technical means for stimulating tight and low permeability reservoirs to improve the production, which is widely employed in the development of unconventional energy resources, including shale gas, shale oil, gas hydrate, and dry hot rock. Although significant progress has been made in the simulation of fracturing a single well using two-dimensional Particle Flow Code (PFC2D), the understanding of the multi-well hydraulic fracturing characteristics is still limited. Exploring the mechanisms of fluid-driven fracture initiation, propagation and interaction under multi-well fracturing conditions is of great theoretical significance for creating complex fracture networks in the reservoir. In this study, a series of two-well fracturing simulations by a modified fluid-mechanical coupling algorithm were conducted to systematically investigate the effects of injection sequence and well spacing on breakdown pressure, fracture propagation and stress shadow. The results show that both injection sequence and well spacing make little difference on breakdown pressure but have huge impacts on fracture propagation pressure. Especially under hydrostatic pressure conditions, simultaneous injection and small well spacing increase the pore pressure between two injection wells and reduce the effective stress of rock to achieve lower fracture propagation pressure. The injection sequence can change the propagation direction of hydraulic fractures. When the in-situ stress is hydrostatic pressure, simultaneous injection compels the fractures to deflect and tend to propagate horizontally, which promotes the formation of complex fracture networks between two injection wells. When the maximum in-situ stress is in the horizontal direction, asynchronous injection is more conducive to the parallel propagation of multiple hydraulic fractures. Nevertheless, excessively small or large well spacing reduces the number of fracture branches in fracture networks. In addition, the stress shadow effect is found to be sensitive to both injection sequence and well spacing.

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A review: Enhanced recovery of natural gas hydrate reservoirs

Cited by 68 publications

References 103 publications

Enhanced CH4-CO2 Hydrate Swapping in the Presence of Low Dosage Methanol

Enhanced CH4-CO2 Hydrate Swapping in the Presence of Low Dosage Methanol

Molecular insight into carbon dioxide hydrate formation from saline solution

Numerical Investigation of Injection-Induced Fracture Propagation in Brittle Rocks with Two Injection Wells by a Modified Fluid-Mechanical Coupling Model

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