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Relevant bibliographies by topics / Injectivité du CO2

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Academic literature on the topic 'Injectivité du CO2'

Author: Grafiati

Published: 25 May 2024

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Journal articles on the topic "Injectivité du CO2"

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Sokama-Neuyam, Yen Adams, Jann Rune Ursin, and Patrick Boakye. "Experimental Investigation of the Mechanisms of Salt Precipitation during CO2 Injection in Sandstone." C 5, no. 1 (2019): 4. http://dx.doi.org/10.3390/c5010004.

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Deep saline reservoirs have the highest volumetric CO2 storage potential, but drying and salt precipitation during CO2 injection could severely impair CO2 injectivity. The physical mechanisms and impact of salt precipitation, especially in the injection area, is still not fully understood. Core-flood experiments were conducted to investigate the mechanisms of external and internal salt precipitation in sandstone rocks. CO2 Low Salinity Alternating Gas (CO2-LSWAG) injection as a potential mitigation technique to reduce injectivity impairment induced by salt precipitation was also studied. We fo

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Guo, Boyun, and Peng Zhang. "Injectivity Assessment of Radial-Lateral Wells for CO2 Storage in Marine Gas Hydrate Reservoirs." Energies 16, no. 24 (2023): 7987. http://dx.doi.org/10.3390/en16247987.

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The carbon dioxide (CO2) leak from conventional underground carbon storage reservoirs is an increasing concern. It is highly desirable to inject CO2 into low-temperature reservoirs so that CO2 can be locked inside the reservoir in a solid state as CO2 hydrates. Marine gas hydrate reservoirs and surrounding water aquifers are attractive candidates for this purpose. However, the nature of the low permeability of these marine sediments hinders the injection of CO2 on a commercial scale due to the low injectivity of wells with conventional completions. This study investigates the injection of CO2

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Carpenter, Chris. "CO2 Injectivity Test Proves Concept of CCUS Field Development." Journal of Petroleum Technology 76, no. 02 (2024): 63–65. http://dx.doi.org/10.2118/0224-0063-jpt.

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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216673, “CO2 Injectivity Test Proves the Concept of CCUS Field Development,” by Yermek Kaipov, SPE, and Bertrand Theuveny, SLB, and Ajay Maurya, Saudi Aramco, et al. The paper has not been peer reviewed. _ The complete paper presents a unique case study on injectivity tests done in Saudi Arabia to prove the concept of carbon capture, use, and storage (CCUS) capability. It describes the design of surface and downhole testing systems, lessons learned, and recommendations. The injectivity tests were

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Rogers, John D., and Reid B. Grigg. "A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process." SPE Reservoir Evaluation & Engineering 4, no. 05 (2001): 375–86. http://dx.doi.org/10.2118/73830-pa.

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Summary This paper summarizes the hypotheses and theories relating to the causes and expectations of injectivity behavior in various CO2 and gasflooded reservoirs. The intent of the paper is to:Provide a concise compendium to the current understanding of the water-alternating-gas (WAG) mechanism and predictability.Provide a comprehensive single-source review of the causes and conditions of injectivity abnormalities in CO2/gasflood EOR projects.Aid in formulating the direction of research.Help operators develop operational and design strategies for current and future projects, as well as to inp

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Ganesh, Priya Ravi, and Srikanta Mishra. "Reduced Physics Modeling of CO2 Injectivity." Energy Procedia 63 (2014): 3116–25. http://dx.doi.org/10.1016/j.egypro.2014.11.336.

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Gasda, Sarah, and Roman Berenblyum. "Intermittent CO2 injection: injectivity and capacity." Baltic Carbon Forum 2 (October 13, 2023): 18–19. http://dx.doi.org/10.21595/bcf.2023.23643.

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Сarbon capture and storage (CCS), especially offshore, involves a chain of complex and expensive infrastructure connecting emitters to the disposal site. The classic example of an industrial cluster sending CO2 by a large pipeline to a nearby storage site is considered the most favorable solution in term of techno-economics. However, many emitters are located either too far from suitable offshore geology or are dispersed in harder to reach locations, making pipeline transport uneconomical. In these instances, ship transport is a viable option for shuttling CO2 from source to sink. The Northern

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Gong, Jiakun, Yuan Wang, Raj Deo Tewari, Ridhwan-Zhafri B. Kamarul Bahrim, and William Rossen. "Effect of Gas Composition on Surfactant Injectivity in a Surfactant-Alternating-Gas Foam Process." Molecules 29, no. 1 (2023): 100. http://dx.doi.org/10.3390/molecules29010100.

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Aqueous foam is a dispersion of gas in liquid, where the liquid acts as the continuous phase and the gas is separated by thin liquid films stabilized by a surfactant. Foam injection is a widely used technique in various applications, including CO2 sequestration, enhanced oil recovery, soil remediation, etc. Surfactant-alternating-gas (SAG) is a preferred approach for foam injection, and injectivity plays a vital role in determining the efficiency of the SAG process. Different gases can be applied depending on the process requirements and availability. However, the underlying mechanisms by whic

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Heidarabad, Reyhaneh Ghorbani, and Kyuchul Shin. "Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity." Energies 17, no. 5 (2024): 1201. http://dx.doi.org/10.3390/en17051201.

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Recently, there has been a growing interest in utilizing depleted gas and oil reservoirs for carbon capture and storage. This interest arises from the fact that numerous reservoirs have either been depleted or necessitate enhanced oil and gas recovery (EOR/EGR). The sequestration of CO2 in subsurface repositories emerges as a highly effective approach for achieving carbon neutrality. This process serves a dual purpose by facilitating EOR/EGR, thereby aiding in the retrieval of residual oil and gas, and concurrently ensuring the secure and permanent storage of CO2 without the risk of leakage. I

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Ziaudin Ahamed, M. Nabil, Muhammad Azfar Mohamed, M. Aslam Md Yusof, Iqmal Irshad, Nur Asyraf Md Akhir, and Noorzamzarina Sulaiman. "Modeling the Combined Effect of Salt Precipitation and Fines Migration on CO2 Injectivity Changes in Sandstone Formation." Journal of Petroleum and Geothermal Technology 2, no. 2 (2021): 55. http://dx.doi.org/10.31315/jpgt.v2i2.5421.

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Carbon dioxide, CO2 emissions have risen precipitously over the last century, wreaking havoc on the atmosphere. Carbon Capture and Sequestration (CCS) techniques are being used to inject as much CO2 as possible and meet emission reduction targets with the fewest number of wells possible for economic reasons. However, CO2 injectivity is being reduced in sandstone formations due to significant CO2-brine-rock interactions in the form of salt precipitation and fines migration. The purpose of this project is to develop a regression model using linear regression and neural networks to correlate the

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Yu, Shuman, and Shun Uchida. "Geomechanical effects of carbon sequestration as CO2 hydrates and CO2-N2 hydrates on host submarine sediments." E3S Web of Conferences 205 (2020): 11003. http://dx.doi.org/10.1051/e3sconf/202020511003.

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Over the past 10 years, more than 300 trillion kg of carbon dioxide (CO2) have been emitted into the atmosphere, deemed responsible for climate change. The capture and storage of CO2 has been therefore attracting research interests globally. CO2 injection in submarine sediments can provide a way of CO2 sequestration as solid hydrates in sediments by reacting with pore water. However, CO2 hydrate formation may occur relatively fast, resulting decreasing CO2 injectivity. In response, nitrogen (N2) addition has been suggested to prevent potential blockage through slower CO2-N2 hydrate formation p

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Dissertations / Theses on the topic "Injectivité du CO2"

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Issautier, Benoit. "Impact des hétérogénéités sédimentaires sur le stockage géologique du CO2." Thesis, Aix-Marseille 1, 2011. http://www.theses.fr/2011AIX10136.

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La démarche d’intégration des hétérogénéités dans les modèles réservoirs en est à ses prémices dans le domaine du stockage géologique de CO2. C’est dans ce contexte que s’inscrivent ces travaux de thèse. Un protocole d’analyse depuis l’étude de terrain jusqu’aux simulations réservoirs a été établi. La caractérisation du Minjur Sandstone (formation Triasique d’Arabie Centrale) met en avant le caractère crucial de la connectivité des corps dans l’architecture du réservoir, notamment en liant génétiquement leur nature, leur connectivité et leur position dans la séquence de dépôt. S’appuyant sur l

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Osselin, Florian. "Thermochemical-based poroelastic modelling of salt crystallization, and a new multiphase flow experiment : how to assess injectivity evolution in the context of CO2 storage in deep aquifers." Phd thesis, Université Paris-Est, 2013. http://pastel.archives-ouvertes.fr/pastel-00977430.

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In a context of international reduction of greenhouse gases emissions, CCS (ce{CO2} Capture and Storage) appears as a particularly interesting midterm solution. Indeed, geological storage capacities may raise to several millions of tons of ce{CO2} injected per year, allowing to reduce substantially the atmospheric emissions of this gas. One of the most interesting targets for the development of this solution are the deep saline aquifers. These aquifers are geological formations containing brine whose salinity is often higher than sea water's, making it unsuitable for human consumption. However

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Ndjaka, Ange. "THERMOPHYSICAL PROCESSES AND REACTIVE TRANSPORT MECHANISMS INDUCED BY CO2 INJECTION IN DEEP SALINE AQUIFERS." Electronic Thesis or Diss., Pau, 2022. http://www.theses.fr/2022PAUU3003.

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Le stockage du CO2 dans les aquifères salins profonds a été reconnu comme l'une des voies les plus prometteuses pour atténuer les émissions atmosphériques de CO2 et répondre ainsi aux enjeux du changement climatique. Cependant, l’injection du CO2 dans le milieu poreux perturbe considérablement son équilibre thermodynamique. La zone proche du puits d’injection est particulièrement impactée avec une forte réactivité géochimique associée à d’intenses échanges thermiques. Cela a un impact majeur sur l’injectivité du réservoir et l’intégrité du stockage. A ces effets s’ajoute une complexité supplém

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Raza, Arshad. "Reservoir Characterization for CO2 Injectivity and Flooding in Petroleum Reservoirs, offshore Malaysia." Thesis, Curtin University, 2017. http://hdl.handle.net/20.500.11937/57524.

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Reservoir characterization of the Malaysian gas reservoir for CO2 storage is carried out at preliminary and comprehensive level to provide insight into the storage capacity, injectivity, trapping mechanisms (structural, capillary, dissolution, and mineral), and containment. Screening tools are proposed in this study for the selections of reservoir, injection well, and injection zone along with CO2 residual trapping novel method, experimental assessment of compaction effect and numerical modeling scheme to improve the reservoir characterization.

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Syed, Shafiuddin Amer. "Permeability and injectivity enhancement of the near wellbore region fo CO2 enhanmced coalbed methane recovery and CO2 storage." Thesis, Imperial College London, 2011. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.534965.

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Beinashor, R. "Effect of halite (NaCl) on sandstone permeability and well injectivity during CO2 storage in saline aquifers." Thesis, University of Salford, 2017. http://usir.salford.ac.uk/44572/.

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Carbon dioxide capture and storage (CCS) is one of the widely discussed options for decreasing CO<sub>2</sub> emissions. This method requires the techniques for capturing purification of anthropogenic CO<sub>2</sub> from fossil-fuel power plants, subsequent compression and transport, and, ultimately, its storage in deep geological formations. Due to the high formation salinity, there is a substantial concern about the near well bore formation dry out as a result salt precipitation in the form of halite (NaCl). The focus was on one of the important physical mechanisms of CO<sub>2</sub> injectio

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Osselin, Florian. "Modélisation thermochimique et poroélastique de la cristallisation de sel, et nouveau dispositif expérimental d'écoulement multiphasique : comment prédire l'évolution de l'injectivité pour le stockage du CO2 en aquifère profond ?" Phd thesis, Université Paris-Est, 2013. http://tel.archives-ouvertes.fr/tel-00958697.

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Dans un contexte de réduction internationale des émissions de gaz à effet de serre, les techniques de Captage Transport et Stockage de CO2 (CTSC) apparaissent comme une solution à moyen terme particulièrement efficace. En effet, les capacités de stockage géologique pourraient s'élever jusqu'à plusieurs millions de tonnes de CO2 injectées par an, soit une réduction substantielle des émissions atmosphériques de ce gaz. Une des cibles privilégiées pour la mise en place de cette solution sont les aquifères salins profonds. Ces aquifères sont des formations géologiques contenant une saumure dont la

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Uzun, Ilkay. "Use Of Pore Scale Simulators To Understand The Effects Of Wettability On Miscible Carbon Dioxide Flooding And Injectivity." Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/2/12606876/index.pdf.

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This study concentrates on the modelling of three phase flow and miscible CO2 flooding in pore networks that captures the natural porous medium of a reservoir. That is to say, the network, that is a Matlab code, consists of different sided triangles which are located randomly through the grids. The throats that connect the pores are also created by the model. Hence, the lengths and the radii of the throats are varying. The network used in this research is assumed to be representative of mixed-wet carbonates in 2-D. Mixed wettability arises in real porous media when oil renders surfaces it come

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Tian, Liang. "CO2 storage in deep saline aquifers : Models for geological heterogeneity and large domains." Doctoral thesis, Uppsala universitet, Luft-, vatten och landskapslära, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-279382.

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This work presents model development and model analyses of CO2 storage in deep saline aquifers. The goal has been two-fold, firstly to develop models and address the system behaviour under geological heterogeneity, second to tackle the issues related to problem scale as modelling of the CO2 storage systems can become prohibitively complex when large systems are considered. The work starts from a Monte Carlo analysis of heterogeneous 2D domains with a focus on the sensitivity of two CO2 storage performance measurements, namely, the injectivity index (Iinj) and storage efficiency coefficient (E

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Sánchez, Jesús Antonio García. "Estudo do fenômeno da auto-intersecção em um anel anisotrópico." Universidade de São Paulo, 2008. http://www.teses.usp.br/teses/disponiveis/18/18134/tde-05022009-100510/.

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Estuda-se numericamente uma placa circular homogênea com furo centrado sob estado plano de deformação. A placa está fixa ao longo do contorno interno e está sob compressão radial uniforme ao longo do contorno externo. O material da placa é elástico-linear e anisotrópico. Apresenta-se a solução analítica do problema, a qual satisfaz as equações governantes de equilíbrio, no contexto da elasticidade linear clássica. Esta solução prediz o comportamento espúrio da auto-intersecção em uma região central da placa. Para evitar este comportamento, utiliza-se uma teoria que propõe encontrar um campo de

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Book chapters on the topic "Injectivité du CO2"

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A. Sokama-Neuyam, Yen, Muhammad A.M. Yusof, and Shadrack K. Owusu. "CO₂ Injectivity in Deep Saline Formations: The Impact of Salt Precipitation and Fines Mobilization." In Carbon Sequestration [Working Title]. IntechOpen, 2022. http://dx.doi.org/10.5772/intechopen.104854.

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Climate change is now considered the greatest threat to global health and security. Greenhouse effect, which results in global warming, is considered the main driver of climate change. Carbon dioxide (CO2) emission has been identified as the largest contributor to global warming. The Paris Agreement, which is the biggest international treaty on Climate Change, has an ambitious goal to reach Net Zero CO2 emission by 2050. Carbon Capture, Utilization and Storage (CCUS) is the most promising approach in the portfolio of options to reduce CO2 emission. A good geological CCUS facility must have a high storage potential and robust containment efficiency. Storage potential depends on the storage capacity and well injectivity. The major target geological facilities for CO2 storage include deep saline reservoirs, depleted oil and gas reservoirs, Enhanced Oil Recovery (EOR) wells, and unmineable coal seams. Deep saline formations have the highest storage potential but challenging well injectivity. Mineral dissolution, salt precipitation, and fines mobilization are the main mechanisms responsible for CO2 injectivity impairment in saline reservoirs. This chapter reviews literature spanning several decades of work on CO2 injectivity impairment mechanisms especially in deep saline formations and their technical and economic impact on CCUS projects.

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FOKKER, P., and L. VANDERMEER. "The Injectivity of Coalbed CO2 Injection Wells." In Greenhouse Gas Control Technologies - 6th International Conference. Elsevier, 2003. http://dx.doi.org/10.1016/b978-008044276-1/50088-x.

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Goodarzi, Somayeh, Antonin Settari, Mark Zoback, and David W. "Thermal Effects on Shear Fracturing and Injectivity During CO2 Storage." In Effective and Sustainable Hydraulic Fracturing. InTech, 2013. http://dx.doi.org/10.5772/56311.

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Mackay, E. J. "Modelling the injectivity, migration and trapping of CO 2 in carbon capture and storage (CCS)." In Geological Storage of Carbon Dioxide (CO2). Elsevier, 2013. http://dx.doi.org/10.1533/9780857097279.1.45.

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SHI, J., and S. DURUCAN. "A numerical simulation study of the Allison Unit CO2-ECBM pilotThe impact of matrix shrinkage and swelling on ECBM production and CO2 injectivity." In Greenhouse Gas Control Technologies 7. Elsevier, 2005. http://dx.doi.org/10.1016/b978-008044704-9/50044-6.

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Conference papers on the topic "Injectivité du CO2"

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Zakrisson, Johan, Ingrid Edman, and Yildiray Cinar. "Multiwell Injectivity for CO2 Storage." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/116355-ms.

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Nagineni, Venu Gopal Rao, Richard Gary Hughes, David D'Souza, and Kenneth Michael Deets. "Evaluation of CO2 Injectivity From Waterflood Values." In SPE Western Regional Meeting. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/132624-ms.

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Jin, M., E. J. Mackay, S. A. Mathias, J. G. Gluyas, W. H. Goldthorpe, and G. E. Pickup. "On the Sensitivity of CO2 Injectivity to Reservoir Facies Architecture." In Fourth EAGE CO2 Geological Storage Workshop. EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20140122.

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McMillan, Burton, Navanit Kumar, and Steven Lawrence Bryant. "Time-Dependent Injectivity During CO2 Storage in Aquifers." In SPE Symposium on Improved Oil Recovery. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/113937-ms.

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André, L. "Well Injectivity during CO2 Storage Operations in Deep Saline Aquifers." In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412023.

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Crawshaw, J. P., and E. S. Boek. "Asphaltene Precipitation and Deposition from a Heavy Crude Oil with CO2." In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412008.

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Ali*, Syed Anas, Jay R. Black, and Ralf Haese. "Geochemical Stimulation in Siliciclastic Reservoirs to Enhance CO2 Injectivity." In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2210548.

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Alkan, H., and Y. Cinar. "Effects of Capillarity and Solubility in Brine on CO2 Injectivity into an Aquifer." In First EAGE CO2 Geological Storage Workshop. European Association of Geoscientists & Engineers, 2008. http://dx.doi.org/10.3997/2214-4609.20146171.

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Snippe, J. "Long-term Fate of Injected CO2 into a Carbonate Formation, Middle East." In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412021.

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Anabaraonye, B., M. J. Blunt, J. P. Crawshaw, A. M. Leal, J. C. Maitland, and C. Peng. "Chemical Interactions between CO2-saturated Brines and Carbonate Minerals at Reservoir Conditions." In First EAGE Workshop on Well Injectivity and Productivity in Carbonates. EAGE Publications BV, 2015. http://dx.doi.org/10.3997/2214-4609.201412022.

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Reports on the topic "Injectivité du CO2"

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Yoshida, Nozomu, and Philip H. Stauffer. Influence of relative permeability parameters on CO2 injectivity. Office of Scientific and Technical Information (OSTI), 2013. http://dx.doi.org/10.2172/1091808.

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