Carbon dioxide injection into useless aquifers and recovery of natural gas dissolved in fossil water

Koide, Hitoshi; Tazaki, Yoshiyuki; Noguchi, Yasuhisa; Iijima, Masaki; Ito, Kazuitsu; Shindo, Yuji

doi:10.1016/0196-8904(93)90037-b

Cited by 29 publications

(3 citation statements)

References 1 publication

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The various aspects of CO 2 sequestering in deep saline aquifers have been studied extensively in the literature [16][17][18][19][20][21][22][23][24][25][26][27][28][29][30][31][32][33] .…”

Section: Co 2 Sequestration In Deep Saline Aquifersmentioning

confidence: 99%

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Basbug¹,

Gumrah²,

Oz³

2005

Canadian International Petroleum Conference

View full text Add to dashboard Cite

CO 2 is one of the hazardous greenhouse gases causing significant changes in the environment. The sequestering CO 2 in a suitable geological media can be feasible method to avoid the negative effects of CO 2 emissions in the atmosphere. A numerical model was developed regarding the CO 2 sequestration in a deep saline aquifer. The compositional numerical model (GEM) of the CMG software was used to study the ability of the selected aquifer to accept and retain large quantities of CO 2 injected in a supercritical state for long periods of time (200 years).Supercritical CO 2 is a one-state fluid which exhibits both gas and liquid-like properties. In this study, supercritical CO 2 was sequestered in three forms in a deep saline aquifer. It was assumed to be supplied an isothermal condition during the injection and sequestration processes and ignored porosity, permeability changes due to the mineralization. Also, CO 2 adsorption was not considered in our numerical model. Gas bubble formation, dissolution of CO 2 in brine and precipitation of CO 2 with calcite mineral in aquifers have been discussed. The CO 2 gas bubble displaces the formation water with an immiscible behavior. During and after the displacement, the gravitational effects cause the CO 2 to raise and accumulate under the caprock. Vertical to horizontal permeability ratio, initial pressure conditions were the most dominating parameters affecting the CO 2 saturation in three layers whereas CO 2 injection rate influenced CO 2 saturation in layers 2 and 3 since CO 2 was injected from layer 3 at the bottom of the reservoir. Salinity of the formation water has no significant effect on CO 2 saturation since it was the main factor affecting the dissolution process.

show abstract

“…The various aspects of CO 2 sequestering in deep saline aquifers have been studied extensively in the literature [16][17][18][19][20][21][22][23][24][25][26][27][28][29][30][31][32][33] .…”

Section: Co 2 Sequestration In Deep Saline Aquifersmentioning

confidence: 99%

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Basbug¹,

Gumrah²,

Oz³

2005

Canadian International Petroleum Conference

View full text Add to dashboard Cite

show abstract

“…The wide global distribution of saline aquifers and their occurrence close to the potential CO 2 emission sources, such as coal-fired power plants, is particularly appealing [3]. The storage capacity of deep saline aquifers for CO 2 is very large and has been estimated to be as low as 320 Gt CO 2 [4] and as high as 200,000 Gt CO 2 [5].…”

Section: Introductionmentioning

confidence: 99%

Understanding of Long-Term CO₂-Brine-Rock Geochemical Reactions Using Numerical Modeling and Natural Analogue Study

Zhu

Tian

et al. 2019

Geofluids

View full text Add to dashboard Cite

To further understand the interactions of CO2-brine-rock at geological time scales, in this study, a 1D reactive transport model of CO2 intrusion into sandstone of the Longtan Formation (P2l) in the Huangqiao area, China, was constructed based on site-specific data. The simulation time is consistent with the retention time of CO2 in the Longtan sandstone Formation and is set to 20 Ma. The reactive transport model is calibrated and revised using the measured data for sandstone samples from Well X3 (i.e., the natural analogue). By comparing the simulation results with measured data for the natural analogue, the long-term geochemical reactions are investigated. The simulation results indicate that the brine-rock interactions induced by CO2 can be roughly divided into two stages. First, susceptible minerals (e.g., chlorite, ankerite, calcite, and feldspar minerals) dissolve rapidly under acidic conditions formed by the dissolution of CO2. The precipitation of siderite is facilitated by the dissolution of ankerite and chlorite. Smectite-Ca and dawsonite precipitate due to the dissolution of anorthite and albite, respectively. Dawsonite begins to convert into smectite-Na when albite is completely dissolved. As the reactions continue, intermediate products (i.e., illite, smectite-Na, and smectite-Ca) generated in the first stage become the reactants and subsequently react with CO2 and brine. These three clay minerals are not stable under acidic conditions and transform into kaolinite and paragenetic quartz in the later stage of reaction. Comparing the simulation results of the Base Case with the measured data for the natural analogue and inspired by previous studies, the scour of kaolinite is supposed to have occurred in this region and is considered in the revised model by introducing a coefficient of the scour of kaolinite (i.e., Case 2). The simulation results of Case 2 fit well with the measured data on mineral assemblage, and the trend of the sandstone porosity growth caused by the CO2-brine-rock reaction is captured by our simulation results. The combination of numerical simulation and natural analogue study indicates that the joint effects of long-term CO2-brine-rock reactions and scour of kaolinite increase the pore space of the host rock and result in an increase in quartz content in the sandstone.

show abstract

“…• Sequestration in these formations does not present health risks [4]. Several studies have been performed to establish the feasibility of CO 2 sequestration in geological formations [7,1,5].…”

Section: Introductionmentioning

confidence: 99%

Maximizing storage rates and capacity of carbon dioxide sequestration in saline reservoirs

Abou-Sayed¹,

Guo²,

Graham³

et al. 2006

WIT Transactions on Ecology and the Environment, Vol 99

View full text Add to dashboard Cite

show abstract

Carbon dioxide injection into useless aquifers and recovery of natural gas dissolved in fossil water

Cited by 29 publications

References 1 publication

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Understanding of Long-Term CO₂-Brine-Rock Geochemical Reactions Using Numerical Modeling and Natural Analogue Study

Maximizing storage rates and capacity of carbon dioxide sequestration in saline reservoirs

Contact Info

Product

Resources

About

Carbon dioxide injection into useless aquifers and recovery of natural gas dissolved in fossil water

Cited by 29 publications

References 1 publication

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Simulating the Effects of Deep Saline Aquifer Properties on COSequestration

Understanding of Long-Term CO2-Brine-Rock Geochemical Reactions Using Numerical Modeling and Natural Analogue Study

Maximizing storage rates and capacity of carbon dioxide sequestration in saline reservoirs

Contact Info

Product

Resources

About

Understanding of Long-Term CO₂-Brine-Rock Geochemical Reactions Using Numerical Modeling and Natural Analogue Study