Impact of physical phenomena and cyclical reinjection in miscible CO2-WAG recovery in carbonate reservoirs

Sampaio, Misako U.; Mello, Samuel Ferreira de; Schiozer, Denis José

doi:10.1007/s13202-020-00925-1

Cited by 12 publications

(3 citation statements)

References 39 publications

(55 reference statements)

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“…In most cases, the scCO 2 is injected continuously into the formation until abandonment. The injection of CO 2 or scCO 2 into porous media has been extensively studied over recent decades, primarily focusing on improving oil recovery in enhanced oil recovery (EOR), with less attention paid to improving CO 2 storage [49][50][51][52][53][54]. One such challenge is the excessive production of CO 2 injected alongside the oil.…”

Section: Injection Strategy As a Means Of Reducing Wamentioning

confidence: 99%

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Eyitayo,

Talal,

Kolawole

et al. 2024

Energies

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Carbon capture and storage (CCS) has been recognized as a pivotal technology for mitigating climate change by reducing CO2 emissions. Storing CO2 in deep saline aquifers requires preserving the water-wet nature of the formation throughout the storage period, which is crucial for maintaining rock integrity and storage efficiency. However, the wettability of formations can change upon exposure to supercritical CO2 (scCO2), potentially compromising storage efficiency. Despite extensive studies on various factors influencing wettability alteration, a significant research gap remains in understanding the effects of different CO2 injection strategies on wettability in deep saline formations (DSFs). This study addresses this gap by investigating how three distinct CO2 injection strategies—continuous scCO2 injection (CCI), water alternating with scCO2 injection (WAG), and simultaneous water and scCO2 injection (SAI)—affect the wettability of gray Berea sandstone and Indiana limestone, both selected for their homogeneous properties relevant to CCS. Using a standardized sessile drop contact angle method before and after CO2 injection, along with core flooding to model the injection process at an injection pressure of 1500 psi and temperature of 100 °F with a confining pressure of 2500 psi, the results indicate a shift in wettability towards more CO2-wet conditions for both rock types under all strategies with changes in CA of 61.6–83.4° and 77.6–87.9° and 81.5–124.2° and 94.6–128.0° for sandstone and limestone, respectively. However, the degree of change varies depending on the injection strategy: sandstone exhibits a pronounced response to the CCI strategy, with up to a 77% increase in contact angle (CA), particularly after extended exposure. At the same time, WAG shows the least change, suggesting that water introduction slows surface modification. For limestone, the changes in CA ranged from 9% to 49% across strategies, with WAG and SAI being more effective in altering its wettability. This study underscores the importance of selecting suitable CO2 injection strategies based on rock type and wettability characteristics to maximize carbon storage efficiency. The findings offer valuable insights into the complex interactions of fluid–rock systems and a guide for enhancing the design and implementation of CCS technologies in various geological settings.

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Section: Injection Strategy As a Means Of Reducing Wamentioning

confidence: 99%

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Eyitayo,

Talal,

Kolawole

et al. 2024

Energies

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“…Through systematically summarizing the recent progresses and research results about CO 2 -EOR, we found that the effect of the water component should be one of the important influencing factors that deserves to be paid attention but has been overlooked. In many practice situations, water may have made a huge impact but went unnoticed.…”

Section: Introductionmentioning

confidence: 99%

“…Investigating the mechanisms and the influencing factors to discover clues that overcome the bottleneck problems is important for the development of the technique. Through systematically summarizing the recent progresses and research results about CO 2 -EOR, 31 we found that the effect of the water component should be one of the important influencing factors that deserves to be paid attention but has been overlooked. In many practice situations, water may have made a huge impact but went unnoticed.…”

Section: Introductionmentioning

confidence: 99%

Critical Contribution of Water in Hybrid CO₂/Water Enhanced Shale Oil Recovery: Insights from Molecular Dynamics

Xue,

Ji,

Wen

et al. 2024

Energy Fuels

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The development of unconventional reservoirs through gas injection has gained significant attention in recent years. CO 2 -enhanced recovery of shale oil is acknowledged to have great prospects but still faces challenges, such as unsatisfactory recovery efficiency. In this study, molecular dynamics (MD) simulations were performed to investigate the displacement behavior of shale oil using a hybrid CO 2 /water flooding system in calcite nanoslits under reservoir conditions. The simulation results demonstrate that pure CO 2 is effective at displacing octane molecules but not efficient enough for displacing asphaltene molecules within the calcite nanoslits, which actually causes the essential obstacle for the effective enhanced oil recovery. Introducing a suitable amount of water into the CO 2 phase significantly enhances the recovery of shale oil, including asphaltene components. It was found that water molecules have high adsorption capacity on the calcite surface, thereby playing a critical role in displacing asphaltenes, while the water phase has difficulties in permeating through the alkane oil layer, and pure water flooding could not achieve a good effect. By interacting with CO 2 molecules, water molecules can easily permeate into the oil phase, and the potential of mean forces (PMFs) analyzation indicated that the desorption of asphaltene molecules from the calcite surface with water existing requires less energy with CO 2 −water coexisting than in a pure CO environment. The hybrid CO 2 /water flooding system could efficiently improve the recovery of asphaltene molecules and get high shale oil recovery. The effect of water contents and injection rate on flooding efficiency was also studied. This work illustrates the microscopic mechanism of hybrid CO 2 /water fluids for replacing shale oil in calcite nanoslits; the results offer new perspectives for optimizing current shale oil extraction techniques and might be helpful in finding more efficient ways to significantly improve the recovery of shale oil.

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Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

Santos

Fioravanti

Botechia

et al. 2023

J Petrol Explor Prod Technol

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Enhancing oil recovery in reservoirs with light oil and high gas content relies on optimizing the miscible water alternating gas (WAG) injection profile. However, this can be costly and time-consuming due to computationally demanding compositional simulation models and numerous other well control variables. This study introduces WAGeq, a novel approach that expedites the convergence of the optimization algorithm for miscible water alternating gas (WAG) injection in carbonate reservoirs. The WAGeq leverages production data to create flexible solutions that maximize the net present value (NPV) of the field, while providing practical implementation of individual WAG profiles for each injector. The WAGeq utilizes an injection priority index to rank the wells and determine which should inject water or gas at each time interval. The index is built using a parametric equation that considers factors such as producer and injector relationship, water cut (WCUT), gas–oil ratio (GOR), and wells cumulative gas production, to induce desirable effects on production and WAG profile. To evaluate WAGeq’s effectiveness, two other approaches were compared: a benchmark solution named WAGbm, in which the injected fluid is optimized for each well over time, and a traditional baseline strategy with fixed 6-month WAG cycles. The procedures were applied to a synthetic simulation case (SEC1_2022) with characteristics of a Brazilian pre-salt carbonate field with karstic formations and high CO2 content. The WAGeq outperformed the baseline procedure, improving the NPV by 6.7% or 511 USD million. Moreover, WAGeq required fewer simulations (less than 350) than WAGbm (up to 2000), while delivering a slightly higher NPV. The terms of the equation were also found to be essential for producing a WAG profile with regular patterns on each injector, resulting in a more practical solution. In conclusion, WAGeq significantly reduces computational requirements while creating consistent patterns across injectors, which are crucial factors to consider when planning a practical WAG strategy.

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Impact of physical phenomena and cyclical reinjection in miscible CO2-WAG recovery in carbonate reservoirs

Cited by 12 publications

References 39 publications

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Critical Contribution of Water in Hybrid CO₂/Water Enhanced Shale Oil Recovery: Insights from Molecular Dynamics

Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

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Impact of physical phenomena and cyclical reinjection in miscible CO2-WAG recovery in carbonate reservoirs

Cited by 12 publications

References 39 publications

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

Critical Contribution of Water in Hybrid CO2/Water Enhanced Shale Oil Recovery: Insights from Molecular Dynamics

Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

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Critical Contribution of Water in Hybrid CO₂/Water Enhanced Shale Oil Recovery: Insights from Molecular Dynamics