Multiphysics coupling in exploitation and utilization of geo-energy: State-of-the-art and future perspectives

Wan, Yizhao; Yuan, Yilong; Zhou, Chao; Liu, Lele

doi:10.46690/ager.2023.10.02

Cited by 9 publications

(3 citation statements)

References 49 publications

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“…The proposed methodology was calculated for the case of porosity = 0.09. The following testing of the suggested approach for high porosities will illustrate its applicability for estimating the potential of natural hydrate-bearing sediments [27,28].…”

Section: Discussionmentioning

confidence: 99%

The Possibility of Estimating the Permafrost’s Porosity In Situ in the Hydrocarbon Industry and Environment

Eppelbaum

2024

Geosciences

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Global warming firstly influences the permafrost regions where numerous and rich world hydrocarbon deposits are located. Permafrost thawing has caused severe problems in exploring known hydrocarbon deposits and searching for new targets. This process is also dangerous for any industrial and living regions in cold regions. Knowledge of permafrost’s ice and unfrozen water content is critical for predicting permafrost behavior during the water–ice transition. This is especially relevant when ice and permafrost are melting in many regions under the influence of global warming. It is well known that only part of the formation’s pore water turns into ice at 0 °C. After further lowering the temperature, the water phase transition continues, but at gradually decreasing rates. Thus, the porous space is filled with ice and unfrozen water. Laboratory data show that frozen formations’ mechanical, thermal, and rheological properties strongly depend on the moisture content. Hence, porosity and temperature are essential parameters of permafrost. In this paper, it is shown that by combining research in three fields, (1) geophysical exploration, (2) numerical modeling, and (3) temperature logging, it is possible to estimate the porosity of permafrost in situ. Five examples of numerical modeling (where all input parameters are specified) are given to demonstrate the procedure. This investigation is the first attempt to quantitatively analyze permafrost’s porosity in situ.

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Section: Discussionmentioning

confidence: 99%

The Possibility of Estimating the Permafrost’s Porosity In Situ in the Hydrocarbon Industry and Environment

Eppelbaum

2024

Geosciences

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“…The gas hydrate content of the eastern segment of the Pacific gas hydrate belt is considered in detail and described in [19][20][21]. Numerical modeling and experimental measurements deal with gas hydrate dissociation and formation and related physical parameters [22,23]. Paper [24] presents the research of multiphase flow and heat transfer in porous matters as well as calculation of the effect on the relative permeability of hydrate-containing deposits.…”

Section: Background and Overviewmentioning

confidence: 99%

Cold Seeps and Heat Flow: Gas Hydrate Provinces Offshore Sakhalin Island

Syrbu,

Kholmogorov,

Maltseva

et al. 2024

Water

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Gas hydrates were found in bottom sediments on the western slope of the Kuril Basin from the side of the Terpeniya Gulf (Okhotsk Sea) at 1020 m depths during expeditions in 2012 and 2013. However, on the eastern slope of the Tatar Strait, gas hydrates were sampled at an unusually shallow 322 m depth. During our research, we identified gas hydrate provinces based on both bottom water and sediment temperature measurement data and heat flow, earthquake, cold seep and sea current data analyses. These provinces have similar hydrological regimes, providing suitable temperature conditions for the existence of gas hydrates, to those at a 322 m depth in the Tatar Strait (Japan Sea) and at 725 and 1020 m depths on the slope of the Kuril Basin (Okhotsk Sea).

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“…A total of 1 m 3 of gas hydrate contains about 164 m 3 of natural gas and 0.8 m 3 of water. The total carbon content of natural gas hydrate in nature is about twice the total carbon content of conventional fossil 2 of 27 fuel resources, which is considered the most important energy alternative in the world due to its huge reserves and high energy density [4][5][6]. With such abundant natural gas hydrate resource reserves, a series of feasible extraction methods have been proposed, such as the depressurization production method, the heat injection extraction method, the gas displacement extraction method, and the chemical reagent injection development method [7][8][9].…”

Section: Introductionmentioning

confidence: 99%

A Review on Submarine Geological Risks and Secondary Disaster Issues during Natural Gas Hydrate Depressurization Production

Ma,

Jiang,

Yan

et al. 2024

JMSE

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The safe and efficient production of marine natural gas hydrates faces the challenges of seabed geological risk issues. Geological risk issues can be categorized from weak to strong threats in four aspects: sand production, wellbore instability, seafloor subsidence, and submarine landslides, with the potential risk of natural gas leakage, and the geological risk problems that can cause secondary disasters dominated by gas eruptions and seawater intrusion. If the gas in a reservoir is not discharged in a smooth and timely manner during production, it can build up inside the formation to form super pore pressure leading to a sudden gas eruption when the overburden is damaged. There is a high risk of overburden destabilization around production wells, and reservoirs are prone to forming a connection with the seafloor resulting in seawater intrusion under osmotic pressure. This paper summarizes the application of field observation, experimental research, and numerical simulation methods in evaluating the stability problem of the seafloor surface. The theoretical model of multi-field coupling can be used to describe and evaluate the seafloor geologic risk issues during depressurization production, and the controlling equations accurately describing the characteristics of the reservoir are the key theoretical basis for evaluating the stability of the seafloor geomechanics. It is necessary to seek a balance between submarine formation stability and reservoir production efficiency in order to assess the optimal production and predict the region of plastic damage in the reservoir. Prediction and assessment allow measures to be taken at fixed points to improve reservoir mechanical stability with the numerical simulation method. Hydrate reservoirs need to be filled with gravel to enhance mechanical strength and permeability, and overburden need to be grouted to reinforce stability.

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Multiphysics coupling in exploitation and utilization of geo-energy: State-of-the-art and future perspectives

Cited by 9 publications

References 49 publications

The Possibility of Estimating the Permafrost’s Porosity In Situ in the Hydrocarbon Industry and Environment

The Possibility of Estimating the Permafrost’s Porosity In Situ in the Hydrocarbon Industry and Environment

Cold Seeps and Heat Flow: Gas Hydrate Provinces Offshore Sakhalin Island

A Review on Submarine Geological Risks and Secondary Disaster Issues during Natural Gas Hydrate Depressurization Production

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