Frontier science and challenges on offshore carbon storage

doi:10.1007/s11783-023-1680-6

Frontiers of Environmental Science & Engineering

2023, Vol. 17

Issue (7): 80 https://doi.org/10.1007/s11783-023-1680-6

本期目录

Frontier science and challenges on offshore carbon storage

Haochu Ku¹, Yihe Miao^1,², Yaozu Wang^1,², Xi Chen^1,⁷, Xuancan Zhu³(

), Hailong Lu⁴, Jia Li^5,⁶, Lijun Yu¹(

)

¹. College of Smart Energy, Shanghai Jiao Tong University, Shanghai 200240, China
². China-UK Low Carbon College, Shanghai Jiao Tong University, Shanghai 201306, China
³. Research Center of Solar Power & Refrigeration, School of Mechanical Engineering, Shanghai Jiao Tong University, Shanghai 200240, China
⁴. Beijing International Center for Gas Hydrate, School of Earth and Space Sciences, Peking University, Beijing 100871, China
⁵. The Hong Kong University of Science and Technology (Guangzhou), Nansha 511458, China
⁶. Jiangmen Laboratory for Carbon and Climate Science and Technology, Jiangmen 529100, China
⁷. School of Environmental Science and Engineering, Shanghai Jiao Tong University, Shanghai 200240, China

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Abstract：

● The main direct seal up carbon options and challenges are reviewed.

● Ocean-based CO₂ replacement for CH₄/oil exploitation is presented.

● Scale-advantage of offshore CCS hub is discussed.

Carbon capture and storage (CCS) technology is an imperative, strategic, and constitutive method to considerably reduce anthropogenic CO₂ emissions and alleviate climate change issues. The ocean is the largest active carbon bank and an essential energy source on the Earth’s surface. Compared to oceanic nature-based carbon dioxide removal (CDR), carbon capture from point sources with ocean storage is more appropriate for solving short-term climate change problems. This review focuses on the recent state-of-the-art developments in offshore carbon storage. It first discusses the current status and development prospects of CCS, associated with the challenges and uncertainties of oceanic nature-based CDR. The second section outlines the mechanisms, sites, advantages, and ecologic hazards of direct offshore CO₂ injection. The third section emphasizes the mechanisms, schemes, influencing factors, and recovery efficiency of ocean-based CO₂-CH₄ replacement and CO₂-enhanced oil recovery are reviewed. In addition, this review discusses the economic aspects of offshore CCS and the preponderance of offshore CCS hubs. Finally, the upsides, limitations, and prospects for further investigation of offshore CO₂ storage are presented.

Key words： Offshore carbon storage Direct CO₂ injection CO₂-CH₄ replacement CO₂-EOR CCS hubs CO₂ transport

收稿日期: 2022-07-04 出版日期: 2023-02-03

Corresponding Author(s): Xuancan Zhu,Lijun Yu

引用本文:

. [J]. Frontiers of Environmental Science & Engineering, 2023, 17(7): 80.
Haochu Ku, Yihe Miao, Yaozu Wang, Xi Chen, Xuancan Zhu, Hailong Lu, Jia Li, Lijun Yu. Frontier science and challenges on offshore carbon storage. Front. Environ. Sci. Eng., 2023, 17(7): 80.

链接本文:

https://academic.hep.com.cn/fese/CN/10.1007/s11783-023-1680-6
https://academic.hep.com.cn/fese/CN/Y2023/V17/I7/80

Tab.1

Fig.1

Fig.2

Tab.2

Fig.3

Fig.4

Factor type	Rection condition	Remarks	CH₄ recovery	Reference
Thermodynamic	20 W, 50 W, 100 W	Higher temperature results in lower efficiency.	85% (20 W)52% (50 W)32% (100 W)	Tupsakhare and Castaldi (2019)
Thermodynamic	267–275 K (2.90 MPa)273.5 K (1.50–3.80 MPa)	Replacement percentage increases with pressure decreasing or temperature increasing.	/	Zhao et al. (2015)
Thermodynamic	274.2 K (2.1–3.1 MPa)3.4 MPa (274.2–281.2 K)	Both temperature and pressure increase facilitate the recovery efficiency.	46.6% (Best, 281.2 K, 3.4 MPa)	Fan et al. (2017)
Thermodynamic	< 273 K (3.6, 4.0, 4.5 MPa)	Higher pressure contributes to higher efficiency.	13.2% (4.5 MPa)	Zhang et al. (2018)
Thermodynamic	275 K (3, 4, 5 MPa)3 MPa (275, 277, 279 K)	Lower pressure and higher temperature contribute to higher efficiency.	44.6% (277 K, 3 MPa)	Chen et al. (2018)
Thermodynamic	275.3 K (8.5, 10.6, 14.5 MPa)	Depressurization is beneficial to methane recovery	44% (8.5 MPa)	Shi et al. (2020)
Auxiliary gas	Pure CO₂Flue gas (20% CO₂ + 80% N₂)	The introduction of N₂ is conducive to methane recovery.	64% (pure CO₂, sI)85% (N₂ + CO₂, sI)	Park et al. (2006)
Auxiliary gas	Pure CO₂Flue gas (10% CO₂ + 90% N₂)	A higher concentration of CO₂ is accompanied by more stable mixed hydrates.	41% (Best, N₂ + CO₂)	Pandey and Solms (2019)
Auxiliary gas	CO₂:H₂ (72:28, 55:45,36:64, 18:82)	High H₂ concentration causes high CH₂ recovery but less CO₂ storage.	72% (Best, CO₂:H₂ = 18:82)	Wang et al. (2017)
Hydrate structure	Structure IStructure II	Structure II hydrates spontaneously transform to sI type.	85% (sI)92% (sII)	Park et al. (2006)
Hydrate structure	Structure IStructure H	Structure H hydrates spontaneously transform to sI type.	68% (sI)88% (sH)	Lee et al. (2015)
CO₂ phase	CO₂ emulsion (CO₂: H₂O = 90:10, 70:30, 50:50)and liquid CO₂	CO₂ emulsion is more advantageous than CO₂ liquid in CO₂-CH₄ replacement.	8.1%–18.6% (100:0)13.1%−27.1% (90:10)14.1%–25.5% (70:30)14.6%–24.3% (50:50)	Yuan et al. (2014)
CO₂ phase	Supercritical CO₂	Supercritical CO₂ transfers more heat to activate dissociation.	3.4% (275 K)40.7% (281 K)10.7% (283 K)	Deusner et al. (2012)
Production methods	CO₂ injection andpressure oscillation	Recovery efficiency increases with the decrease of pressure.	15.95%–27.54%(2.92–1.74?MPa)	Sun et al. (2021)
Production methods	CO₂ injection and thermal simulation (one step, continuous, and stepwise)	Combined methods can increase efficiency by 8.21%–34.79%; stepwise heating is the best.	69.51% (stepwise)	Lv et al. (2021)
Injection rate	275 K, 3 MPa (1.5, 1.0, 0.5)(Rate unit: mL/min)	Initial recovery efficiency increases with injection rate within some scopes.	/	Chen et al. (2018)

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