Leakage risk assessment of a CO2 storage site: A review

Gholami, Raoof; Raza, Arshad; Iglauer, Stefan

doi:10.1016/j.earscirev.2021.103849

Cited by 158 publications

(49 citation statements)

References 161 publications

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“…Given that the technology is advancing quickly, biological monitoring demands exploration. Leakages also can manifest due to geochemical interaction and temperature/pressure differentials between the CO2 and the host rock in which it is injected (Gholami et al 2021). Biological monitoring has more potential in detecting leaks and other environmental changes that happen due to those leakages (Nobel et al 2012).…”

Section: B2 Depleted Hydrocarbon Reservesmentioning

confidence: 99%

The development of carbon capture and storage (CCS) in India: A critical review

Shaw¹,

Mukherjee²

2022

Preprint

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Carbon capture and sequestration (CCS) is a three-tier process- carbon capture, transport andstorage. The capture consists of pre-combustion, oxy-combustion and post-combustion capture.Transport of CO2 is most viable through pipelines.The biotic CO2storage occurs throughterrestrial or oceanic pathways and can be simulated naturally or artificially. The abiotic/geologicstorage is achieved through sequestering CO2 in depleting/depleted hydrocarbon reserves, indeep saline aquifers or through mineral carbonation. At the district level, 64 out of 641 districts(2013 government reports) accounted for ~ 60% of the total CO2 emissions. Controlling CO2emissions comes with the challenge of sustainable socio-economic growth of the country- ademanding task for the economy. Indian organizations have made international collaborations.India holds a substantial geological sequestration potential in its basaltic rocks, coal seams,depleted oil reserves, soils, deep saline aquifers and sedimentary basins. At this point, no carboncapture and storage / clean development mechanism projects are operational in the country. Thenext 10-15 years would be very crucial for India to attain technological advancement to deploylarge-scale CCS projects.

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Section: B2 Depleted Hydrocarbon Reservesmentioning

confidence: 99%

The development of carbon capture and storage (CCS) in India: A critical review

Shaw¹,

Mukherjee²

2022

Preprint

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“…Carbon capture, utilisation and storage (CCUS) technology is recognised as one effective solution for reducing CO 2 emissions in the atmosphere 1,2 . In this technology, CO 2 is captured, transported, used, or stored permanently in porous geological media 3–5 . CCUS includes two main pathways where CO 2 is used either as a solvent or feedstock for engineering chemicals, fuels, carbonates and polymers 6 or as a displacement agent to enhance oil, gas, or heat production.…”

Section: Introductionmentioning

confidence: 99%

“…1,2 In this technology, CO 2 is captured, transported, used, or stored permanently in porous geological media. [3][4][5] CCUS includes two main pathways where CO 2 is used either as a solvent or feedstock for engineering chemicals, fuels, carbonates and polymers 6 or as a displacement agent to enhance oil, gas, or heat production. CO 2 -enhanced oil recovery (CO 2 -EOR) is an established technology in the oil and gas industry.…”

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confidence: 99%

Full‐scale simulation of a nearly depleted gas field in South Africa for carbon utilisation and storage

et al. 2022

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Enhanced gas recovery (EGR) is a recognised CO2 utilisation technique that can reduce the cost of carbon storage and improve its economic feasibility. Although there are many studies on the potential of depleted gas fields for CO2 storage, there has not been a comprehensive full‐scale study that can analyse different aspects of carbon utilisation together with the potential of storage, from reservoir characterisation to modelling and economic evaluation. The aim of this study is to develop a benchmark for assessing the technical and economic feasibility of carbon utilisation and storage in abandoned and nearly depleted gas fields. A depleted gas field from the Bredasdorp Basin in South Africa was selected for CO2‐EGR and storage, given the availability of data and infrastructure. The reservoir of interest is divided into compartments, with this study focusing exclusively on compartment C1. The gas in place (Gi) in compartment C1 was 5.8E+08 MSCF, which was reduced to 3.33E+08 MSCF at the end of the primary production phase. The results obtained indicated that the gas reservoir is very heterogeneous, and a recovery of 20% can be achieved if the injection and production rates are 500 and 3000 MSCF/day, respectively. The amount of CO2 injected after 71 years was about 7.78E+07 MSCF. It was shown that the CO2 in this field can be injected for 71 years without causing problems with the integrity of the reservoir. The economic model was built assuming a project duration of 10 years. The model shows that the total cost of carbon capture, transport and storage is higher than the total revenue for 8 years of natural gas utilisation, which means that the amount of gas recovered from compartment C1 of the reservoir could not offset the cost of CCUS. It is recommended that additional data be collected for the C2 compartment, the carbon capture processes at the Mossel Bay GTL plant, and pipeline transportation to reduce the uncertainty of the proposed economic model. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Chemical mechanisms in geological reservoirs are of key importance in many subsurface processes, for example, rock diagenesis, , deposition of precious metals, , hydrocarbon formation and migration, − groundwater quality, − CO 2 geo-sequestration, − and, more recently, H 2 geo-storage. − …”

Section: Introductionmentioning

confidence: 99%

“…In a different context, over the last few years, the geological storage of CO 2 has been increasingly considered a promising approach toward a green environment where CO 2 is permanently immobilized in deep underground formations of the earth’s subsurface, for instance, depleted oil/gas reservoirs, aquifers, or coal bed seams. ,,− Here, the injected CO 2 dissolves in the formation brine and establishes acidic conditions, , which in turn induces geochemical interactions with the formed minerals that lead to the dissolution of minerals, for example, carbonates, feldspar, kaolinite, calcite, chlorite, or clays . These interactions directly affect the reservoir permeability, porosity, rock strength, and capillary pressure, and hence, the flow of CO 2 through the porous media along with CO 2 storage capacity.…”

Section: Introductionmentioning

confidence: 99%

Effect of Inorganic Acid Concentration on Sandstone Surface Chemistry Examined via Nuclear Magnetic Resonance

et al. 2022

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Despite rock surface charge being a critical component in predicting the reservoir behavior, the subsurface characteristics are still poorly understood, specially, those of sandstones, which are of key economic importance in the oil and gas industry. Even though a rock surface is originally considered to be neutrally charged, surface charges are created in the presence of water and dissolved ions. Moreover, a major proportion of sandstone reservoirs are composed of silica which creates surface charges through dissociation of silanols in the presence of water and/or acids. Rock subsurface chemistry is a primary factor that determines the variability of several key reservoir parameters (e.g., capillary pressures or residual saturations). Nuclear magnetic resonance (NMR) is a well-established tool with which such rock surface chemistry can be measured in situ. For example, surface charge is a vital characteristic with which single-phase and multiphase fluid flow behavior can be predicted (e.g., it determines colloidal stabilities or streaming potentials); the surface charge/surface potential is thus highly significant for a wide range of applications and processes, for example, enhanced oil/gas recovery, hydrogen/CO 2 geo-storage, or contaminant transport. This study provides novel insights into fundamental rock surface chemistry and how this is influenced by the acidity of the aqueous phase in the subsurface. Specifically, we systematically examined sandstone surface chemistry as a function of mineral acid concentration via NMR T 2 response measurements. For this, Bentheimer sandstone samples were treated with aqueous hydrochloric acid solutions of different concentrations, and NMR T 2 distribution measurements were performed for the initial and treated samples. The results indicated that higher concentrations of hydrochloric acid (and thus more surface protonation) yielded much shorter T 2 relaxation times compared to lower concentrations. This work thus provides fundamental information about in situ sandstone surface chemistry and therefore aids in the basic understanding and implementation of key geologic questions and engineering projects.

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Leakage risk assessment of a CO2 storage site: A review

Cited by 158 publications

References 161 publications

The development of carbon capture and storage (CCS) in India: A critical review

The development of carbon capture and storage (CCS) in India: A critical review

Full‐scale simulation of a nearly depleted gas field in South Africa for carbon utilisation and storage

Effect of Inorganic Acid Concentration on Sandstone Surface Chemistry Examined via Nuclear Magnetic Resonance

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