A review of chemical-assisted minimum miscibility pressure reduction in CO2 injection for enhanced oil recovery

Almobarak, Mohamed; Wu, Zangyuan; Zhou, Deyun; Fan, Kun; Liu, Yongbing; Xie, Quan

doi:10.1016/j.petlm.2021.01.001

Cited by 40 publications

(17 citation statements)

References 63 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The recovery factor (RF) increases with pressure until a break-over point is reached, as depicted in Figure , where the curve slope changes at about 90% RF . The MMP from this test aligns well with the simulation if very accurate reservoir data are taken. ,,,, Yet, a combination of IFT and slim-tube methods has rarely been used to estimate MMP. Thus, this study was conducted to minimize the uncertainties by comparing MMP results from both techniques.…”

Section: Introductionsupporting

confidence: 61%

See 1 more Smart Citation

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

et al. 2023

View full text Add to dashboard Cite

The effectiveness of CO2-enhanced oil recovery (EOR) is strongly dependent on the CO2–oil minimum miscible pressure (MMP) value, which can be estimated using various methods. In this study, interfacial tension (IFT) and slim-tube tests were used to estimate the MMP value. Experimental results indicated that the IFT test had a higher MMP value than the slim-tube test. Particularly, the outcomes of IFT and the slim-tube tests differed slightly, i.e., 0.7% and 4.3% at 60 and 66 °C, respectively. Furthermore, the current work also compares MMP data gathered using visual observation and equation of state (EOS) simulation. The MMP estimated by EOS is higher but close to the IFT and slim-tube recovery factor method, where all results are within the 1650–1700 psi and 1700–1800 psi visual observation ranges at 60 and 66 °C, respectively. However, MMP deviations concerning the slim-tube test and EOS were consistent at different temperatures. This study offers an alternative to estimate and evaluate CO2–oil MMP for EOR applications accurately and efficiently.

show abstract

Section: Introductionsupporting

confidence: 61%

“…17 The MMP from this test aligns well with the simulation if very accurate reservoir data are taken. 6,11,13,14,21 Yet, a combination of IFT and slim-tube methods has rarely been used to estimate MMP. Thus, this study was conducted to minimize the uncertainties by comparing MMP results from both techniques.…”

Section: Introductionmentioning

confidence: 99%

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

et al. 2023

View full text Add to dashboard Cite

show abstract

“…The minimum miscibility pressure (MMP) is a key criterion when designing for injection pressure (IP) during gas EOR (Mohamed et al 2021). When the IP is below the MMP, there is no significant oil recovery; however, when the IP is higher than the MMP, there will be a significant increase in oil recovery.…”

Section: Optimization Of Injection Pressurementioning

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

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.

show abstract

“…However, due to the low viscosity and low density of the gas, the gas drive is strongly influenced by the non-homogeneity of the reservoir, and the gas injection process is often faced with poor control of gas fluidity and problems such as viscous finger entry, gravitational overburden, the gas scramble, and so forth. High flowability of gas will reduce sweep efficiency and adversely affect enhanced oil recovery. , In addition to the sealing technology, the existing methods to improve the recovery of CO 2 flooding are mostly focused on reducing the minimum miscible pressure to implement miscible flooding, increasing the viscosity of the displacement phase CO 2 to adjust the mobility and sweep ability. − Related studies show that it is more important to increase the macroscopic sweep volume of the CO 2 flooding than to reduce the minimum mixing pressure during the CO 2 injection drive. Given that fluid density is mainly influenced by the formation environment (temperature and pressure), CO 2 fluidity control techniques are mostly studied in the direction of increasing the viscosity of the injected fluid, such as water–air alternation, depth migration-controlled CO 2 foam, supercritical CO 2 microemulsion, direct CO 2 viscosity enhancement, and so forth.…”

Section: Introductionmentioning

confidence: 99%

Evaluation of the Driving Effect of the CO₂ Viscosity Enhancer Composite System in Extra-Low Permeability Sandstone Reservoirs

Dong

Wang

et al. 2023

ACS Omega

View full text Add to dashboard Cite

CO2 flooding is an important technology to enhance oil recovery and realize effective storage of CO2 in ultra-low permeability reservoir. However, due to poor reservoir properties, strong interlayer heterogeneity, and unfavorable mobility ratio of CO2, gas channeling easily occurs, resulting in low recovery. Chemically assisted CO2 thickening technology has been developed to control the gas flow rate and improve the CO2 repulsion effect. Through solubility and viscosity enhancement tests, the CO2 viscosity enhancer composite system is preferably constructed and then combined with the core drive experiments, the effect of CO2 viscosity enhancer composite system on oil drive in homogeneous and non-homogeneous cores is evaluated, the correlation between the drive efficiency and viscosity enhancement and solubility of the system is analyzed, and the mechanism of recovery enhancement is explored. The results show that the preferably constructed CO2–ASA-LAP composite system has a good effect for improving the gas drive effect under simulated formation conditions, and its improvement effect is positively related to the solubility and viscosity increase of the system. Combining oil repelling efficiency and economic considerations, ASA:LAP = 1:1 is selected as the optimal CO2 viscosity enhancer composite oil repelling system. For homogeneous cores, the CO2–ASA-LAP combined system drive can increase the recovery rate by 6.65% as compared with CO2 flooding. For heterogeneous cores, when the permeability difference is 5, the comprehensive recovery factor of the CO2–ASA-LAP system flooding is 8.14% higher than that of CO2 flooding. When the permeability difference increases from 5 to 10, the comprehensive recovery factor of the CO2–ASA-LAP system flooding increases by 1.85%.The injection of the CO2–ASA-LAP system has some injurious effect on the permeability of the reservoir core, and the smaller the permeability, the greater the degree of injury. The mechanism of the CO2–ASA-LAP system to improve recovery includes increasing CO2 viscosity, improving the oil repelling flow ratio, blocking high seepage channels, initiating low seepage residual oil, enhancing CO2 dissolution, and expanding the oil repelling effect.

show abstract

A review of chemical-assisted minimum miscibility pressure reduction in CO2 injection for enhanced oil recovery

Cited by 40 publications

References 63 publications

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

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

Evaluation of the Driving Effect of the CO₂ Viscosity Enhancer Composite System in Extra-Low Permeability Sandstone Reservoirs

Contact Info

Product

Resources

About

A review of chemical-assisted minimum miscibility pressure reduction in CO2 injection for enhanced oil recovery

Cited by 40 publications

References 63 publications

Minimum CO2 Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

Minimum CO2 Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

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

Evaluation of the Driving Effect of the CO2 Viscosity Enhancer Composite System in Extra-Low Permeability Sandstone Reservoirs

Contact Info

Product

Resources

About

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

Minimum CO₂ Miscibility Pressure Evaluation using Interfacial Tension (IFT) and Slim-tube Hybrid Tests

Evaluation of the Driving Effect of the CO₂ Viscosity Enhancer Composite System in Extra-Low Permeability Sandstone Reservoirs