Immiscible and miscible gas-oil displacements in porous media

Kulkarni, Madhav M.

doi:10.31390/gradschool_theses.259

Cited by 11 publications

(3 citation statements)

References 33 publications

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“…CO 2 -EOR is acknowledged as the second most extensive EOR method deployed globally, following thermal EOR processes utilized in heavy oil fields. 8 CO 2 injection offers several advantages: simplicity leading to lower operational costs, higher oil recovery efficiency, especially in those reservoirs with less heterogeneity resulting in the continuous and sustained displacement of oil toward production wells, faster response in terms of oil production, lower water production mitigating water handling and disposal issues, easier monitoring and control of injection parameters such as injection rates and pressures, etc. However, water-alternating-gas (WAG) injection is often preferred over CO 2 injection for several reasons.…”

Section: Introductionmentioning

confidence: 99%

Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Dutta,

Kundu,

Mousavi Mirkalaei

et al. 2024

Energy Fuels

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After over seven decades of production, most reservoirs in the Upper Assam Sedimentary Basin, India, have reached intermediate or late development stages, rendering them suitable for the adoption of enhanced oil recovery (EOR) techniques. Lighter nature of crude oil and favorable mobility ratio in most of these reservoirs opens up avenues for assessment of CO 2 -EOR, which also offers the added benefit of carbon storage, aligning with global climate change mitigation efforts in addition to incremental oil production. This research aims to evaluate the viability of CO 2 -EOR and potential for permanent storage within the reservoir, as well as to conduct an in-depth analysis of various mechanisms. The subject reservoir ABC001 is located in the Upper Assam Basin, India, which meets the screening criteria for CO 2 -EOR evaluation. Various CO 2 injection strategies have been evaluated in this research, along with the effect of impurities and quantification of trapping mechanisms. The CO 2 -EOR has the potential to enhance recovery from the reservoir to 43.3%, compared to 39.3% from water flood. Even though the recovery is lesser (42.3%) than CO 2 injection, CO 2 water-alternating-gas (WAG) is projected to result in the greatest retention of CO 2 within the reservoir. A total of 306.7 MM m 3 and 153.4 MM m 3 of CO 2 is injected into the reservoir corresponding to CO 2 injection and CO 2 WAG scenarios, out of which around 194.9 MM m 3 and 68.4 MM m 3 are produced, leaving behind around 36.5% and 55.4% of CO 2 in the reservoir, respectively. The CO 2 -EOR and storage studies conducted in this project will enhance the learning curve, facilitating the development of a knowledge base that can be utilized to broaden CCUS initiatives in India.

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Section: Introductionmentioning

confidence: 99%

Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Dutta,

Kundu,

Mousavi Mirkalaei

et al. 2024

Energy Fuels

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“…WAG and SAG in single or multiple stages can be adopted to increase displacement efficiency, fluid contact, and travel time inside the reservoir. 18 The application of CCS technologies, including SAG/WAG injection, and their impact on CO 2 sequestration have also been explored through computational fluid dynamic (CFD) simulations, experimental studies, and field application investigations. It has been found that alternating injection of surfactant solution and CO 2 may greatly enhance displacement efficiency and improve the oil recovery factor (RF) by 14%.…”

Section: Introductionmentioning

confidence: 99%

Three-Phase Fluid Flow Interaction at Pore Scale during Water- and Surfactant-Alternating Gas (WAG/SAG) Injection Using Carbon Dioxide for Geo-Sequestration and Enhanced Oil Recovery

et al. 2023

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Sequestration of CO2 in geologic formations such as depleted oil reservoirs has emerged as one of the lead solutions to tackle greenhouse gas emissions to reduce pollution and global warming. Supercritical CO2 (sc-CO2) injection in oil reservoirs has proven to be useful as an enhanced oil recovery (EOR) technique along with the benefits of CO2 sequestration. In this study, a tortuous microscopic pore scale model was used to study and investigate the phenomena of water-alternating gas (WAG) and surfactant-alternating gas (SAG) with sc-CO2. The study scrutinizes the dynamics of the pore-level phenomenon in the multiphase WAG and SAG flows at the pore level in detail. Transient computational fluid dynamics (CFD) analysis was used to study the fluid flow characteristics of oil, water, and sc-CO2 at different reservoir pressure and temperature conditions in oil-wet conditions. Governing equations were coupled with EOS (Helmholtz free energy equation) to capture the viscous and intrinsic properties of sc-CO2 due to variations in pressure and temperature conditions. It was found that higher oil recovery does not necessarily indicate higher sc-CO2 sequestration and that temperature harms the displacement mechanism due to unfavorable mobility ratios. Comparing WAG and SAG for the first injection cycle, SAG showed a more diffused interface between displaced and displacing fluid. The additional oil recovery produced in patches was a result of pressure oscillations near the blind pores. Moreover, high vorticity promotes greater intermixing between the displacing and displaced fluid by increasing the rate of interface length. In SAG cases, faster sc-CO2 breakthroughs were observed due to reduced shear stress along the fluid interfaces, which resulted in higher sequestration values in a given time frame. The CO2 sequestration volume in SAG cases was found to be approximately 40% more than in WAG experiments. The study confirms that lower values of oil–water interfacial tension aids in faster and more efficient sequestration of sc-CO2 along with additional oil gain from a given reservoir.

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“…Para uma modelagem precisa do fenômeno de histerese, mostra-se necessária uma análise experimental para cada projeto, na qual se deve identificar e separar este parâmetro, para avaliar seu efeito no processo de recuperação [Kulkarni, 2003]. Entretanto, segundo Eleri and Skauge [1995], as curvas de permeabilidade relativa podem ser obtidas a partir de fluidos sintéticos e rochas de afloramento em condição atmosférica, em função do custo e difícil acesso a amostras reais de fluidos e de rochas, além das dificuldades de se reproduzir condições de altas pressões e temperaturas no laboratório.…”

Section: Introductionunclassified

Histerese nas curvas de permeabilidade relativa trifásica em carbonatos usando tomografia computadorizada de raios-x

Machado¹

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Ao Professor Osvair Vidal Trevisan, pela orientação e simpatia; Ao pesquisador Ronaldo Gonçalves dos Santos, por sua disposição em ensinar e pelo acompanhamento ao longo de todo o desenvolvimento do projeto;Ao pesquisador Euclides José Bonet, por todos os questionamentos e pelo bom humor; Aos técnicos Leandro, Washington e James, aos pesquisadores Nilo, Eliana, Pompeu, Alessandra e Fabiana, aos alunos Eddy, Ricardo Freitas Filho, Philipe, Erik, Janeth e Elias, do Laboratório de Métodos Miscíveis de Recuperação, pelo auxílio, companhia e experiências compartilhadas;À toda minha família, por estarem sempre ao meu lado; Ao Enrique, pelo apoio constante e paciência; Aos estudantes Carlos Espinosa, Celso Marques e Leandro Lopes pelo compartilhamento de conhecimentos adquiridos e discussões;Aos companheiros Omar Duran, Eduardo Altoé, Livia de Luca, Mauricio Pardo e Nara Policarpo por todas as lições aprendidas juntos ao longo destes dois anos; Aos professores, por todo conhecimento repassado;

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Immiscible and miscible gas-oil displacements in porous media

Cited by 11 publications

References 33 publications

Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Three-Phase Fluid Flow Interaction at Pore Scale during Water- and Surfactant-Alternating Gas (WAG/SAG) Injection Using Carbon Dioxide for Geo-Sequestration and Enhanced Oil Recovery

Histerese nas curvas de permeabilidade relativa trifásica em carbonatos usando tomografia computadorizada de raios-x

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Immiscible and miscible gas-oil displacements in porous media

Cited by 11 publications

References 33 publications

Evaluation of Potential of CO2-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Evaluation of Potential of CO2-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Three-Phase Fluid Flow Interaction at Pore Scale during Water- and Surfactant-Alternating Gas (WAG/SAG) Injection Using Carbon Dioxide for Geo-Sequestration and Enhanced Oil Recovery

Histerese nas curvas de permeabilidade relativa trifásica em carbonatos usando tomografia computadorizada de raios-x

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Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India

Evaluation of Potential of CO₂-Enhanced Oil Recovery (EOR) and Assessment of Capacity for Geological Storage in a Mature Oil Reservoir within Upper Assam Basin, India