Carbonated water injection: an efficient EOR approach. A review of fundamentals and prospects

Ghosh, Bisweswar; Al-Hamairi, Abdullah; Jin, S.

doi:10.1007/s13202-019-0738-2

Cited by 49 publications

(23 citation statements)

References 72 publications

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“…Therefore, the efficiency of oil transport by gas can be explained by the concept of MMP (Wang et al 2020). When the gas injection is maintained above the MMP, a high oil recovery factor is achieved (Bisweswar et al 2020). However, the MMP is not the same for different gases, and it is generally much higher for N 2 than for CO 2 ; therefore, for an N 2 oil system, the miscibility condition is more difficult to achieve (Bougre et al 2021).…”

Section: Results Of Comparative Simulation Of the Volumetric Sweep Efficiency During Sg Dag And Tag Injectionsmentioning

confidence: 99%

Optimization of triple-alternating-gas (TAG) injection technique for enhanced oil recovery in tight oil reservoirs

Edouard

Dong

Okere

et al. 2021

J Petrol Explor Prod Technol

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After single-gas (SG) injection operations in tight oil reservoirs, a significant amount of oil is still unrecovered. To increase productivity, several sequencing gas injection techniques have been utilized. Given the scarcity of research on multiple-gas alternating injection schemes, this study propose an optimized triple-alternating-gas (TAG) injection for improved oil recovery. The performance of the TAG process was demonstrated through numerical simulations and comparative analysis. First, a reservoir compositional model is developed to establish the properties and composition of the tight oil reservoir; then, a suitable combination for the SG, double alternating gas (DAG), and TAG was selected via a comparative simulation process. Second, the TAG process was optimized and the best case parameters were derived. Finally, based on the oil recovery factors and sweep efficiencies, a comparative simulation for SG, DAG, and TAG was performed and the mechanisms explained. The following findings were made: (1) The DAG and TAG provided a higher recovery factor than the SG injection and based on recovery factor and economic advantages, CO2 + CH4 + H2S was the best choice for the TAG process. (2) The results of the sensitivity analysis showed that the critical optimization factors for a TAG injection scheme are the injection and the production pressures. (3) After optimization, the recovery factor and sweep efficiency of the TAG injection scheme were the best. This study promotes the understanding of multiple-gas injection enhanced oil recovery (EOR) and serves as a guide to field design of gas EOR techniques.

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Section: Results Of Comparative Simulation Of the Volumetric Sweep Efficiency During Sg Dag And Tag Injectionsmentioning

confidence: 99%

Optimization of triple-alternating-gas (TAG) injection technique for enhanced oil recovery in tight oil reservoirs

Edouard

Dong

Okere

et al. 2021

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

show abstract

“…In response, IFT is reduced as a result of the weakened hydrogen bonds among water molecules. Consequently, IFT in the CW-oil interface is less than it in the brine-oil system 12 . Hamouda and Bagalkot 16 reported the same observation when they used carbonated water with MgCl 2 .…”

Section: Wettability Alterationmentioning

confidence: 93%

“…[3][4][5] CW had an enhanced sweep efficiency compared to the other CO 2 -EOR methods such as CO 2 injection and water-alternating-gas (WAG) due to oil viscosity reduction and CW's ability to overcome the shielding effect. 6,12 The shielding prevents the CO 2 (free phase) from being in contact with the oil, but in the carbonated water, the CO 2 is dissolved in the water as an aqueous phase. 3,[13][14][15] When the CO 2 enriched water is in contact with the oil, the CO 2 will diffuse from the aqueous phase to the oil phase, leading to an oil swelling, thus decreasing the oil viscosity, enhancing the ultimate recovery.…”

Section: Carbonated Low Salinity Water Floodingmentioning

confidence: 99%

Mechanistic study of the carbonated smart water in carbonate reservoirs

2021

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Carbonated smart water (CSMW) injection has drawn considerable interest, especially in the last decade. This interest stems from its results in the recovery factor enhancement and the storage of carbon dioxide. This method has been mainly studied for sandstone formations, and less devotion has been given to carbonates, especially in naturally fractured reservoirs. This paper examines the effect of the CSMW on the recovery factor in carbonate homogenous and fractured reservoirs and investigates the most effective mechanisms. Furthermore, the capability of the CSMW to store the CO 2 in the reservoir has been tested. This work has been established based on core flooding experimental data, using a compositional simulator, and extending the core results to a pilot model. The composition and salinity values of the CSMW have been specified using optimization and sensitivity analysis tools. Geochemical reactions and CO 2 solubility in the CSMW have been simulated using the PHREEQC. In the core scale, the CSMW showed 14, 7.6, 26.8% more oil recovery than Smart Water (SMW), Carbonated Seawater (CSW), and Seawater (SW), respectively. In the pilot model, CSMW recovered more oil than the SMW by 5-8% based on the heterogeneity and fracture availability. Viscosity reduction is one of the main mechanisms behind the oil recovery increment. More than 30% of viscosity reduction was observed for all studied cases. Ions exchange and mineral dissolution processes were also pivotal. A higher recovery has been obtained in the fractured reservoir after the breakthrough due to the CO 2 diffusion from the fractures into the matrices and the spontaneous imbibition process, where those mechanisms need a long time to act effectively. More than 50% of the injected CO 2 within the CSMW has been captured in the reservoir's residual oil and water. It has been concluded that the stored CO 2 in the reservoir depends on the amount of residual oil saturation, where the higher the remaining oil in the reservoir, the higher the stored CO 2 amount.

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“…The model was assembled in an oil-industry standard reservoir simulation tool (Eclipse100) with three phases, respectively, representing water (brine), CO 2 (in supercritical state), and CO 2 dissolved in water. CO 2 solubility in brine for the different temperature and pressure was taken from [32], while the corresponding variation in brine density was obtained from [33]. Relative permeabilities were based on actual measurements done in connection with the earlier studies.…”

Section: Actual Field Case Simulationsmentioning

confidence: 99%

Periodic CO2 Injection for Improved Storage Capacity and Pressure Management under Intermittent CO2 Supply

et al. 2022

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Storing CO2 in geological formations is an important component of reducing greenhouse gases emissions. The Carbon Capture and Storage (CCS) industry is now in its establishing phase, and if successful, massive storage volumes would be needed. It will hence be important to utilize each storage site to its maximum, without challenging the formation integrity. For different reasons, supply of CO2 to the injection sites may be periodical or unstable, often considered as a risk element reducing the overall efficiency and economics of CCS projects. In this paper we present outcomes of investigations focusing on a variety of positive aspects of periodic CO2 injection, including pressure management and storage capacity, also highlighting reservoir monitoring opportunities. A feasibility study of periodic injection into an infinite saline aquifer using a mechanistic reservoir model has indicated significant improvement in storage capacity compared to continuous injection. The reservoir pressure and CO2 plume behavior were further studied revealing a ‘CO2 expansion squeeze’ effect that governs the improved storage capacity observed in the feasibility study. Finally, the improved pressure measurement and storage capacity by periodic injection was confirmed by field-scale simulations based on a real geological set-up. The field-scale simulations have confirmed that ‘CO2 expansion squeeze’ governs the positive effect, which is also influenced by well location in the geological structure and aquifer size, while CO2 dissolution in water showed minor influence. Additional reservoir effects and risks not covered in this paper are then highlighted as a scope for further studies. The value of the periodic injection with intermittent CO2 supply is finally discussed in the context of deployment and integration of this technology in the establishing CCS industry.

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Carbonated water injection: an efficient EOR approach. A review of fundamentals and prospects

Cited by 49 publications

References 72 publications

Optimization of triple-alternating-gas (TAG) injection technique for enhanced oil recovery in tight oil reservoirs

Optimization of triple-alternating-gas (TAG) injection technique for enhanced oil recovery in tight oil reservoirs

Mechanistic study of the carbonated smart water in carbonate reservoirs

Periodic CO2 Injection for Improved Storage Capacity and Pressure Management under Intermittent CO2 Supply

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