Numerical Investigation into the Impact of CO<sub>2</sub>-Water-Rock Interactions on CO<sub>2</sub> Injectivity at the Shenhua CCS Demonstration Project, China

Yang, Guodong; Li, Yilian; Atrens, Andrej; Yu, Ying; Wang, Yongsheng

doi:10.1155/2017/4278621

Cited by 23 publications

(15 citation statements)

References 46 publications

(68 reference statements)

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“…In addition, the dissolution and/or precipitation of calcite involves a cascade of simultaneous reactions [ 60 , 61 , 62 , 63 , 64 ], as given thus (Equations (18) , (19) and (20) ): CaCO 3 + H + ↔ Ca 2+ + HCO 3 - CaCO 3 + H 2 CO 3 ↔ Ca 2+ + 2HCO 3 - CaCO 3 + H 2 O ↔ Ca 2+ + HCO 3 - + OH − …”

Section: Resultsmentioning

confidence: 99%

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A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

Aminu

Manović

2020

Heliyon

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Carbon capture and storage (CCS) is expected to play a key role in meeting greenhouse gas emissions reduction targets. In the UK Southern North Sea, the Bunter Sandstone formation (BSF) has been identified as a potential reservoir which can store very large amounts of CO 2 . The formation has fairly good porosity and permeability and is sealed with both effective caprock and base rock, making CO 2 storage feasible at industrial scale. However, when CO 2 is captured, it typically contains impurities, which may shift the boundaries of the CO 2 phase diagram, implying that higher costs will be needed for storage operations. In this study, we modelled the effect of CO 2 and impurities (NO 2 , SO 2 , H 2 S) on the reservoir performance of the BSF. The injection of CO 2 at constant rate and pressure using a single horizontal well injection strategy was simulated for up to 30 years, as well as an additional 30 years of monitoring. The results suggest that impurities in the CO 2 stream affect injectivity differently, but the effects are usually encountered during early stages of injection into the BSF and may not necessarily affect cumulative injection over an extended period. It was also found that porosity of the storage site is the most important factor controlling the limits on injection. The simulations also suggest that CO 2 remains secured within the reservoir for 30 years after injection is completed, indicating that no post-injection leakage is anticipated.

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Section: Resultsmentioning

confidence: 99%

“…In addition, the dissolution and/or precipitation of calcite involves a cascade of simultaneous reactions [60,61,62,63,64], as given thus (Equations ( 18), (19) and ( 20)):…”

Section: Resultsmentioning

confidence: 99%

A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

Aminu

Manović

2020

Heliyon

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“…during CO 2 injection into sandstone cores identified the mobilized fine particles as mainly clay, quartz and cement. Depending on the reaction conditions and formation rock properties, mineral dissolution could improve CO 2 injectivity if the dissolved minerals pipe through the formation as reported by Yang et al . from the Shenhua CCS demonstration project in China.…”

Section: Introductionmentioning

confidence: 90%

The coupled effect of salt precipitation and fines mobilization on CO₂ injectivity in sandstone

Sokama‐Neuyam

Ursin

2018

Greenhouse Gases

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Appreciable CO2 injectivity is required to inject large volumes of CO2 through a minimum number of wells. In situ geochemical CO2‐brine‐rock reactions may dissolve sandstone rock minerals, and consequently release fine particles into the pore fluid. If the fine particles (‘fines’) are mobilized during CO2 injection, well injectivity could be severely impaired. The transport of fines under CO2 injection conditions involves the complex multiphase flow of dry supercritical CO2, saline formation brine, and fine particles. While transported fines could plug narrow pore channels, the saline pore water could be vaporized by supercritical CO2 to precipitate solid salt into the pores. To understand the impact of mineral dissolution on CO2 injectivity, it is important to consider the coupled effect of fine particle mobilization and salt precipitation. We conducted core‐flood experiments and theoretical modelling to investigate the coupled effect of the fines mobilization and salt precipitation on CO2 injectivity. We found that salt precipitation could increase CO2 injectivity impairment induced by the fines mobilization. The deposited salt reduces the flow area, making the pores more susceptible to particle entrapment. Injectivity impairment increased with decreasing initial rock permeability and increasing saturating brine salinity. Irreducible brine saturation and pore size distribution were identified as parameters that strongly determine the contribution of salt precipitation during the transport of fines. Injectivity impairment was also slightly higher when the rock was first exposed to salt precipitation, before the entrapment of fines. The current findings highlight the complexity and uniqueness of fines transportation under CO2 injection conditions and the impact of mineral dissolution on CO2 injectivity. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…can considerably change the rock permeability by affecting the grain size distribution (Lamy- Chappuis et al, 2013;Nogues et al, 2013;Sadhukhan et al, 2012;Yang et al, 2017). Figure 4 presents the effect of pure and impure CO2 on the grain size distribution of the rock samples.…”

Section: Equation 19mentioning

confidence: 99%

CO2-brine-rock interactions: The effect of impurities on grain size distribution and reservoir permeability

Aminu

Nabavi

Manović

2018

International Journal of Greenhouse Gas Control

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The Bunter Sandstone formation in the UK Southern North Sea has been identified as having the potential to store large volumes of CO2. Prior to injection, CO2 is captured with certain amounts of impurities, usually less than 5%vol. The dissolution of these impurities in formation water can cause chemical reactions between CO2, brine, and rock, which can affect the reservoir quality by altering properties such as permeability. In this study, we explored the effect of CO2 and impurities (NO2, SO2, H2S) on reservoir permeability by measuring changes in grain size distributions after a prolonged period of 9 months, simulating in situ experimental conditions. It was found that the effects of pure CO2 and CO2-H2S are relatively small, i.e., CO2 increased permeability by 5.5% and CO2-H2S decreased it by 5.5%. Also, CO2-SO2 slightly decreased permeability by 6.25%, while CO2-NO2 showed the most pronounced effect, reducing permeability by 41.6%. The decrease in permeability showed a correlation with decreasing pH of the formation water and this equally correlates with a decrease in geometric mean of the grain diameter. The findings from this study are aimed to be used in future modelling studies on reservoir performance during injection and storage, which also should account for the shifts in boundaries in the CO2 phase diagram, altering the reservoir properties and affecting the cost of storage.

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Numerical Investigation into the Impact of CO₂-Water-Rock Interactions on CO₂ Injectivity at the Shenhua CCS Demonstration Project, China

Cited by 23 publications

References 46 publications

A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

The coupled effect of salt precipitation and fines mobilization on CO₂ injectivity in sandstone

CO2-brine-rock interactions: The effect of impurities on grain size distribution and reservoir permeability

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Numerical Investigation into the Impact of CO2-Water-Rock Interactions on CO2 Injectivity at the Shenhua CCS Demonstration Project, China

Cited by 23 publications

References 46 publications

A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

A modelling study to evaluate the effect of impure CO2 on reservoir performance in a sandstone saline aquifer

The coupled effect of salt precipitation and fines mobilization on CO2 injectivity in sandstone

CO2-brine-rock interactions: The effect of impurities on grain size distribution and reservoir permeability

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Numerical Investigation into the Impact of CO₂-Water-Rock Interactions on CO₂ Injectivity at the Shenhua CCS Demonstration Project, China

The coupled effect of salt precipitation and fines mobilization on CO₂ injectivity in sandstone