Fig 1 - available via license: CC BY-NC-ND
Content may be subject to copyright.
![Mechanisms and impacts of CO 2 leakage from geological sequestration sites [57]. (Copyright 2016 Springer, reproduced with permission)](publication/325290374/figure/fig1/AS:862583552761856@1582667353898/Mechanisms-and-impacts-of-CO-2-leakage-from-geological-sequestration-sites-57.png)
Mechanisms and impacts of CO 2 leakage from geological sequestration sites [57]. (Copyright 2016 Springer, reproduced with permission)
Source publication
Enhanced oil recovery (EOR) via carbon dioxide (CO2) flooding has received a considerable amount of attention as an economically feasible method for carbon sequestration, with many recent studies focusing on developing enhanced CO2 foaming additives. However, the potential long-term environmental effects of these additives in the event of leakage a...
Context in source publication
Similar publications
Injecting carbon dioxide into oil reservoirs has the potential to serve as an enhanced oil recovery (EOR) technique, mitigating climate change by storing CO2 underground. Despite the successful achievements reported of CO2 to enhance oil recovery, mobility control is one of the major challenges faced by CO2 injection projects. The objective of this...
Foam has been applied in enhanced oil recovery (EOR) for more than sixty years. The surfactant-stabilized N 2 / CO 2 foams are two of the most widely used foams in foam EOR processes, and numerous oil reservoirs could potentially benefit from them. This paper comprehensively reviews the development of these foams over the past decade. We focused on...
Citations
... Polymer injection (Levitt and Pope 2008, Samanta et al. 2011, Samanta et al. 2012, Jung et al. 2013, Sheng 2013, Olajire 2014, Raffa et al. 2016, Bashir, Sharifi Haddad and Rafati 2018, Dang et al. 2018, Gbadamosi et al. 2018a, b, c, Muhammed, Haq et al. 2020a Better control of injected slug Reduction of viscous fingering phenomenon Increasing oil recovery coefficient Reduction of premature passage of water Increase in oil production Need for miscible polymers with high molecular weight High implementation costs Problems related to polymer injection in different reservoir conditions Surfactant injection (Liu et al. 2007;Hirasaki et al. 2011;Samanta et al. 2011;Sun et al. 2014;Bera and Belhaj 2016a, b;Raffa et al. 2016;Abbas et al. 2020;Haq et al. 2020a, b;Al-Ghamdi et al. 2022) Increased oil recovery Reduction of oil-water IFT Changing the properties of wettability Reduction of oil-water IFT Reduction of oil injection and production costs Foam injection (Du et al. 2008;Liu, Andrianov and Rossen 2011;Sun et al. 2014;Singh and Mohanty 2015;Spirov and Rudyk 2015;Rafati et al. 2016;Samin et al. 2017;Bashir, Sharifi Haddad and Rafati 2018;Clark and Santiso 2018;Yekeen et al. 2018;Abdelaal et al. 2020) Increase in injection apparent viscosity Better mobility is improved Expansion of foam bubbles in porous media Selective fluid movement from stealth areas to areas with lower permeability or non-recycling areas Higher efficiency than water flood, gas injection, and watergas flood methods The possibility of producing foam with a longer half-life using chemicals ...
... Foam Foam injection represents a notable method within the GEOR techniques. In the work by Clark and Santiso (Clark and Santiso 2018), an overview of recent advancements in surfactant and surfactant/nanoparticle-based CO 2 foaming is provided, focusing on the potential environmental implications associated with the unintended release of CO 2 foam. The paper reviews developments in CO 2 foaming systems using abrasive materials and their combinations with nanoparticles, assessing their efficacy in enhancing oil recovery while addressing the environmental risks linked to their release. ...
The escalating global population and the surging demand for oil have necessitated the advancement of enhanced oil recovery (EOR) methods to augment production. However, conventional EOR techniques, while effective, contribute substantially to environmental degradation by releasing pollutants and greenhouse gases (GHGs), highlighting the pressing need for more sustainable alternatives. In response, green-enhanced oil recovery (GEOR) has emerged as a transformative solution, incorporating eco-friendly technologies to optimize oil extraction while mitigating environmental impact. This study offers a critical evaluation of various GEOR approaches, including the injection of organic materials, microbial processes, solar energy integration, and the application of nanotechnology. The originality of this research lies in its comparative analysis of cutting-edge GEOR techniques such as Water Alternating Gas (WAG), foam injection, nanofluid injection, smart water flooding, and microbial EOR. Each method is assessed based on performance indicators, environmental repercussions, and operational efficiency. The findings demonstrate that GEOR methods not only enhance oil recovery efficiency but also significantly curtail environmental footprints compared to traditional EOR strategies. By providing an in-depth assessment of these sustainable technologies, this study identifies the most efficient methods while underscoring their unique advantages and limitations. GEOR methods offer eco-friendly solutions with varied advantages, such as WAG's mobility control, foam injection's enhanced sweep efficiency, and nano-fluid's reduced environmental impact. While techniques like smart water and microbial methods minimize chemical use, challenges such as scalability, high costs, and reservoir-specific limitations remain. The results strongly advocate for the broader adoption of GEOR technologies, emphasizing their crucial role in promoting sustainable development and environmental stewardship. This research contributes valuable insights for both academic researchers and industry professionals, encouraging the implementation of GEOR practices to achieve environmentally responsible oil recovery. The comprehensive analysis presented herein serves as an indispensable resource for advancing the domain of sustainable oil recovery practices.
... CO 2 foam is an adequate technique to effectively control gas mobility and enhance displacement efficiency in EOR and carbon sequestration applications (Bello, Ivanova et al., 2023). This strategy has the potential to significantly reduce carbon footprint and extend the life of mature oilfields, thereby contributing to the ongoing sustainable energy supply and transition (Clark and Santiso, 2018). Foam can be generated when a surfactant solution encounters a gas such as carbon dioxide, nitrogen, air, or methane, and adequate mechanical energy is provided that can cause the liquid to generate foam (Stevenson, 2012). ...
Polymer-enhanced CO2 foam (PEF) is an emerging technology for gas mobility control and CO2 storage in geologic formations to mitigate anthropogenic emissions. The foam generated by surfactants alone is prone to film rupture and low endurance, particularly in Middle Eastern carbonates under harsh conditions of high temperature and salinity. Adding polymer to a surfactant solution can enhance foam stability, increase viscosity, and resist liquid drainage. This study presents a systematic polymer-stabilized foam formulation design and optimization. The work particularly focuses on developing foam formulations while incorporating polymer in surfactant formulation to enhance the foaming performance. Anionic surfactants, amphoteric surfactants, associative polymers, and an ATBS-based polymer were tested under high salinity brine (up to 167 kppm) and high temperature (up to 120°C) conditions. The Design of Experiment (DOE) approach was used to formulate the composition of the PEF formulation toward achieving maximum bulk foam stability. The obtained optimized formulation was verified experimentally for its bulk foam properties and further tested in coreflooding experiments using a carbonate outcrop to assess mobility reduction factor (MRF) and CO2 storage potential.
The results showed that selected surfactants, polymers, and combinations were stable at a high temperature of 120°C and a high salinity of 167 kppm; further tests were conducted at 95°C and 105 kppm salinity. The bulk foam stability results indicated that using a combination of surfactants and polymers significantly improved foam stability expressed by the foam’s half-life. To understand the impact of each component, the data was analyzed using various mixture regression models, and the cubic model fitted well with the foam half-life response. Binary-surfactant foam formulations performed better than using a single surfactant system. However, the ternary foam formulation of surfactants with polymer showed a strong interaction and a significant synergistic effect. The optimized polymer-enhanced foam formulation consists of 6201 ppm C-5, 3500 ppm SB, and 183.2 ppm SAV-10 polymer as high as 132 minutes at 95°C and atmospheric pressure. Additionally, the study revealed that polymer addition played a crucial role in enhancing foam longevity. Increasing the polymer concentration to adequate levels helps reduce foam coalescence due to high viscous resistance and strong foam films. Polymer concentration lower than the optimized levels renders foam less stable and weak. On the other hand, a higher concentration than the optimum results in faster foam collapse due to the fast liquid drainage. The coreflooding results showed that the optimized PEF formulation performed exceptionally well in reducing CO2 mobility and enhancing CO2 storage capacity under high-salinity (105 kppm), high-temperature (95°C), and high-pressure (1500 psi) conditions. The optimized PEF formulation generated strong foam in porous media; the mobility reduction factor (MRF) was recorded 50.2, showing higher foam viscosity than gas and brine during the injection. Furthermore, foam flooding with the optimized PEF resulted in a higher CO2 storage capacity of 77.1% compared to 14.8% for gas injection. Previous studies utilized random formulation methods to improve foaming performance by incorporating polymer as a foam stabilizer, neglecting to optimize foam stability requirements. This study is one of the few systematic works to design, optimize, and test the best-performing PEF formulation that can withstand harsh Middle Eastern reservoir conditions, providing in-depth mobility control and ensuring long-term CO2 sequestration.
... Gas injection in tight reservoirs is an essential but risky process encountered in multiple carbon capture, utilization and storage (CCUS) applications [1,2]. Such an attempt to enhance oil recovery (EOR) or accomplish higher CO 2 storage capacity is challenging due to the severe gas channeling caused by unfavorable mobility ratio between the defending wetting fluid, either brine or crude oil, and the immiscible non-wetting gaseous phase injected [3][4][5]. ...
... Schematic of foam fractional flow curve inside tight porous media with varying absolute permeability (test 2,3,8,9). ...
Fractional flow analysis is an efficient tool to evaluate the gas-trapping performance of foam in porous media. The pore-scale simulation study and the core-scale experimental work have been bridged via the fractional flow analysis to distinguish the characteristics of foam displacement inside the tight porous media with varying absolute permeability, injection rate, and foam quality. In this work, the combined investigation suggests that conventional foam-enhancing strategies, pursuing higher foam quality and stronger foam regime, are inefficient and restricted in tight reservoirs that the critical Sw corresponding to the limiting capillary pressure has increased around 37~43%, which indicates severely weakened gas-trapping capacity as permeability reduces one order of magnitude. The moderate mobility adjustment and corresponding optimized fluid injectivity exerting from the “weak foam” flow presents a staged decline feature of decreasing water fractional flow, which implies the existence of the delayed gas-trapping phenomenon when water saturation reduces to 0.5~0.6. The finding has supported the engineering ideal of promoting low-tension gas (LTG) drive processes as a potential solution to assist field gas injection applications suffering from gas channeling. Also, the validation with core-flooding experimental results has revealed several defects of the current pore network model of foam displacement in tight porous media, including exaggerated gas trapping and overestimated confining water saturation. This study has innovatively demonstrated the feasibility and potential of optimizing the foam performance of gas trapping and mobility control in tight reservoirs, which provides a clue that may eventually boost the efficiency of the gas injection process in enhanced oil recovery or CO2 sequestration projects.
... These CO 2 remain stationary even during leakage events, greatly improving the CO 2 geo-sequestration safety [54,55]. Regarding chemical agents leakage, many common foaming agents, such as alpha olefin sulfonate (AOS), and sodium dodecyl sulfate (SDS), bis(2-ethylhexyl) sulfosuccinate (AOT), are toxic to aquatic organisms [56]. In contrast, APG, a sugar-based nonionic surfactant, is efficient, stable and environmentally friendly, providing a significant advantage for future saline aquifer CO 2 geo-sequestration projects. ...
This study investigates the micro-mechanism by which the hydrophobic chain length LHC of alkyl polyglycosides (APGs) affects the stability of CO2 foams, and its influence on the behavior of CO2 sequestration in deep saline aquifers. The results demonstrated that increasing LHC within a specific range (9−11) resulted in enhanced ad-sorption of APG molecules within the bubble liquid film, augmented binding effect of APG on CO2 and water molecules, and improved cation aggregation at the hydrophilic group of APG, thus strengthening the CO2 foam stability. Nevertheless, further LHC increases weakened the water-solubility of APG, and reduced the aggregation of water molecules and cations around the hydrophilic groups of APG molecules, which weakened the mechanical strength of CO2 foam liquid film and its stability. Low-field nuclear magnetic resonance (NMR) showed that as the LHC increased from 9 to 11, the stability of CO2 foam inside the sandstone core is continuously strengthened, and an ideal piston-like displacement formed. Foam not only improved the CO2 storage space in macro-pores, but also enhanced the entrances and displacements of the internal water in the meso- and micro-pores, providing more space for CO2 sequestration. However, further LHC increases weakened the CO2 foam stability inside the sandstone core. Although CO2 foam could occupy many macro-pores, its ability to divert to meso- and micro-pores was weakened, and the CO2 storage capacity in sandstone cores was reduced overall.
... Sources and impacts of CO2 leakage from geological sequestration sites[38]. ...
This study aimed to explore the conventional trends in Carbon Capture and Storage (CCS) and evaluate its potential
as a framework for environmental sustainability. The methodology involved a comprehensive review of research
studies, reports, and case studies related to CCS implementation in various industries and regions. The review
included an assessment of the current status of CCS projects worldwide and their effectiveness in reducing carbon
emissions. The study also examined the regulatory frameworks and policy incentives that support deploying CCS
technologies for environmental sustainability. In addition, the study evaluated different types of CCS technologies
and their effectiveness in capturing and storing CO2 emissions. The evaluation also delved into the environmental
risks and benefits associated with CCS, including potential leakage of stored CO2 and using energy-intensive
processes for capture and storage. The study revealed that several CCS projects have been successfully implemented
in power plants, cement factories, and other industrial facilities, demonstrating the feasibility of capturing and storing
CO2 emissions. However, the high costs associated with CCS deployment remain a significant barrier to widespread
adoption. The lack of public awareness and acceptance of CCS technologies posed challenges to their implementation
on a larger scale. The long-term storage of CO2 and the environmental impacts of CCS operations were some of the
concerns noted about the sustainability of this technology. Despite these challenges, CCS has the potential to play a
crucial role in achieving environmental sustainability by reducing carbon emissions and transitioning to a low-carbon
economy.
... The toxicity of NPs can be characterized by techniques such as cell culture assays, in vivo animal studies, and computational toxicology. These techniques can provide information on the potential health effects of the NPs and can be used to ensure the safety of the NPs for EOR applications [97]. ...
In recent decades, nanotechnology has emerged as a rapidly growing field with diverse applications in industries such as pharmaceuticals, energy, and engineering. One of the key areas of interest is the use of nanoparticles (NPs) and nanofluids (NFs) in Enhanced Oil Recovery (EOR) to improve oil recovery efficiency. NPs offer several benefits in the hydrocarbon industry and have been shown to enhance oil and gas production. In EOR, NPs play a crucial role by interacting with the rock/oil system, optimizing conditions for oil retrieval. They offer a cost-effective and eco-friendly alternative compared to conventional methods. This comprehensive study delves into the diverse range of NPs and nanomaterials utilized in the petroleum industry, detailing their classification, characterization, and inherent properties. It explores multiple applications of NPs in chemical, thermal, and microbial flooding, elucidating the involved mechanisms like wettability modification and mobility control. Moreover, the research examines the utilization of NPs in EOR through image-based modeling, a groundbreaking approach in enhancing EOR techniques. It highlights the considerable progress achieved in EOR through the application of NPs and nanofluids (NFs). Additionally, the study assesses the potential of NPs in image-based modeling and their implications for future EOR applications, indicating a promising trajectory for integrating NPs into the petroleum industry.
... 12 The above research shows a more uniform front of foam that pushes oil rather than fingering through the reservoir's most exposed geological structures. 13 However, as the resistance generated by foam is weaker than that of the gel system, the effect of improving gas flooding in fractured reservoirs is relatively poor. 14 As one of the effective measures to improve water flooding, a gel system has been applied to CO 2 flooding by domestic and foreign scholars. ...
CO2 flooding has been successfully used in numerous oil fields as a strategy to improve oil recovery. However, several issues, including gas channeling, profile control, CO2 sweep efficiency, oil displacement efficiency, etc., have been revealed in the development of CO2 flooding, particularly in a fractured reservoir. In this paper, in view of the focus issues, a novel multistage plugging system is investigated, mainly including the polymer-gel system. The static and dynamic polymer-gel system performances are comprehensively evaluated. Based on the features of a fractured reservoir, a multiscale fracture model is built, and the applicable limits of the polymer-gel system are proposed. When the fracture width is greater than 0.65 mm, the plugging effect of the polymer gel becomes worse. However, the plugging effect is clearly strengthened by the use of polymer gel, foam, and bulk particles, which also significantly improves the injection–production profile. The experimental results show that CO2 flooding could increase the ultimate recovery by 7.67%.
... The Jia Min effect in foam flooding can improve the displacement fluid's swept volume and washing efficiency [5]. A pressure drop funnel would form near the well so that the remaining oil on both sides of the main diagonal line would be used to form an oil wall extending from the mainline to the two sides, forming a longer water-bearing low-value production stage [6]. Nitrogen foam is mainly concentrated near the wellbore. ...
The CFD oilfield is located in the Bohai Sea area and is a typical offshore sandstone reservoir with strong bottom water. The characteristic of the rapid increase in water content is that it quickly enters a highly high water content period, and there currently needed to be more potential tapping measures affected by offshore production facilities. The development mode should be changed to explore the development effect of nitrogen foam flooding. This study conducted two experiments. The first experiment is a gas injection expansion experiment, which studied the changes in bubble point pressure, fluid volume, density, and viscosity under different gas injection conditions. The second experiment used a high-temperature and high-pressure oil displacement device and a long core for oil displacement experiments. Two typical sand bodies were selected for the N2 foam oil displacement experiment. The experimental results show that nitrogen injection has little effect on the properties of reservoir crude oil, with a viscosity reduction effect of 12.4% for heavy oil and 20.0% for thin oil. The viscosity of crude oil significantly impacts the selection of alternative media. The channel was prone to blockage and low oil displacement efficiency when injecting a single gas medium into a heavy oil system. The displacement efficiency of thin oil nitrogen foam is 73.28%. The displacement efficiency of nitrogen foam flooding for heavy oil is 43.09%. This study has a guiding significance for developing development plans for offshore sandstone reservoirs.
... Metode ini disebut juga sebagai metode half-time (Lunkenheimer & Malysa 2003). Efektivitas busa yang terbentuk pada kondisi superkritikal CO 2 ini pada umumnya tidak stabil sehingga dibutuhkan penguat yang dapat menjaga kestabilan busa tersebut (Clark & Santiso 2018). Salah satu penguat yang digunakan adalah dengan penambahan surfaktan dan nanopartikel. ...
Penggunaan busa CO2 untuk metode injeksi cenderung tidak stabil dalam pembentukan stabilitas dari busa. Karena hal itu, dibutuhkan penguat untuk menambahkan stabilitas busa yang terbentuk. Pada penelitian ini, menggunakan nano abu batubara dan nano silika serta polimer berupa xanthan gum sebagai penguat busa. Tujuan dari penelitian ini adalah untuk mengetahui pengaruh dengan penambahan nano dan polimer pada stabilitas busa, perbandingan penggunaan nano abu batubara dan silika dalam uji stabilitas busa serta penelitian ini juga bertujuan untuk mengetahui penguat apa yang dapat meningkatkan stabilitas busa secara signifikan. Metode yang digunakan pada penelitian ini menggunakan metode uji laboratorium yang dimulai dari proses milling sampel, karakterisasi sampel, hingga pengujian stabilitas busa. Pengujian stabilitas busa menggunakan metode yang menghitung waktu halftime. Hasil dari pengujian stabilitas busa ini didapatkan bahwa penambahan nano silika dan nano abu batubara memiliki peningkatan waktu halftime sebesar 10.23% dan 2.96% dibandingkan tidak menggunakan nanopartikel. Campuran dari nanopartikel dan polymer berupa xanthan gum dapat meningkatkan waktu halftime 12.65% untuk nano silika dan 6.33% untuk nano abu batubara. Sedangkan campuran nanopartikel, polimer, dan minyak mengalami penurunan 10.9% untuk nano silika dan 16.29% untuk nano abu batubara. Berdasarkan hasil analisis data percobaan yang sudah dilakukan, penambahan nano silika memiliki nilai stabilitas busa yang lebih tinggi dibandingkan nano abu batubara serta penambahan nano silika dan polimer merupakan penguat yang paling baik dalam menjaga stabilitas dari busa yang dihasilkan
... If the drilling fluid could not reach the level of absolute non-toxic, degrade quickly, and yield environment-friendly degradation products, the degradation products could promote the growth of plants as nutrition or even become a necessary part of native ecological circulation; thus, the passive treatment could be avoided and the environment-friendly drilling fluid could be improved to the ecological drilling fluid. To develop ecological PDF, studies should lay emphasis on the invention of additives made of natural polymers and their derivatives including polysaccharide, poly-amino-acid, protein, and poly-fatty-acid (Mittal et al., 2014;Li et al., 2015;Panda et al., 2017;Jiang et al., 2018c;Clark and Santiso, 2018). Finding inspiration from substances generated in animal and plant metabolism could be an effective way. ...
Unconventional gas includes tight sandstone gas, shale gas, coalbed methane, and natural gas hydrate. With huge reserves, unconventional gas has become the most important natural gas resource successor after the end of the “Easy Oil era.” The drilling fluid is an indispensable wellbore working fluid for unconventional gas drilling with multiple functions. The polymer drilling fluid (PDF) is the most common, longest developed, and most diverse drilling fluid type. With advantages of easily controlled rheology, convenient on-site performance maintenance, and specifically low cost and weak environment pollution, the PDF is gradually replacing the oil-based drilling fluid as the first choice for unconventional gas drilling. The invention of the non-disperse low-solid-content PDF in the 1960s shows that PDF technology has entered the stage of scientific development, and until now, its development has generally experienced five stages: beginning, developing, improving, re-developing, and re-improving. Dozens of polymer additives and PDF systems have been invented and applied, which have solved severe drilling problems, greatly improved drilling efficiency, and promoted exploration and development in difficult oil and gas resources. This paper first reviews the research progress of PDF technology according to the timeline by introducing the composition, feature, advantages, and disadvantages of some representative polymer additives and PDF systems, emphatically the function and mechanism of stabilizing wellbores, lubricating drilling tools, and protecting reservoirs of the biomimetic wellbore-strengthening PDF and amphiphobic high-efficiency PDF in unconventional gas drilling. Then, combining future global demands, especially China’s strategic needs of oil and gas exploration and development, the development tendency of PDF technology is critically illustrated by introducing several potential research directions including intelligent PDF, ecological PDF, and PDF for natural gas hydrate and deep layer gas resources.
