Schweitzer J.-M., M. Elia, C. García, U. Ehrenstein
Processes carrying out exothermic reactions must ensure safe operating conditions to avoid uncontrolled thermal excursion, also known as runaway. Therefore, a thermal stability analysis is necessary to determine the safe and productive range of operating conditions of highly exothermic processes. Hydrotreating gas oil feeds consists mainly of hydrogenation reactions; processing highly unsaturated feeds such as light cycle oils can be highly exothermic. For this reason, a thermal stability study of this complex refining is performed. Perturbations theory has already been applied to carry out a thermal stability study of this process under dynamic conditions. This method consists in the perturbation of the hydrotreating reactor model and solution of the perturbed model in the form of an eigenvalue problem. The stability condition imposes that all perturbations must tend to zero when time tends to infinity. Some methodology and numerical aspects applying this theory and the effect on stability results are tackled in this work. The formalization of the perturbed model solution as a standard eigenvalue problem or as a generalized eigenvalue problem are presented. The computation of the Jacobian by a numerical approach or with the analytical expressions is also carried out. In both cases, results are compared and their influence on the stability/instability results is presented.
{"title":"Thermal Stability of Gas Oil Hydrotreating Processes: Numerical Issues of the Matrix-Eigenvalue Approach Stabilité thermique de procédés d’hydrotraitement des gazoles : aspects numériques de l’approche par valeurs propres matricielles","authors":"Schweitzer J.-M., M. Elia, C. García, U. Ehrenstein","doi":"10.2516/OGST/2010018","DOIUrl":"https://doi.org/10.2516/OGST/2010018","url":null,"abstract":"Processes carrying out exothermic reactions must ensure safe operating conditions to avoid uncontrolled thermal excursion, also known as runaway. Therefore, a thermal stability analysis is necessary to determine the safe and productive range of operating conditions of highly exothermic processes. Hydrotreating gas oil feeds consists mainly of hydrogenation reactions; processing highly unsaturated feeds such as light cycle oils can be highly exothermic. For this reason, a thermal stability study of this complex refining is performed. Perturbations theory has already been applied to carry out a thermal stability study of this process under dynamic conditions. This method consists in the perturbation of the hydrotreating reactor model and solution of the perturbed model in the form of an eigenvalue problem. The stability condition imposes that all perturbations must tend to zero when time tends to infinity. Some methodology and numerical aspects applying this theory and the effect on stability results are tackled in this work. The formalization of the perturbed model solution as a standard eigenvalue problem or as a generalized eigenvalue problem are presented. The computation of the Jacobian by a numerical approach or with the analytical expressions is also carried out. In both cases, results are compared and their influence on the stability/instability results is presented.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82505912","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Seismic effects of the injection of CO2 into a partially depleted oil field have been evaluated. Seismic modelling yields small time-lapse effects, including 0.4 ms time-shifts and 4 to 6% amplitude variations at the top and bottom of the reservoir. Amplitude variations at the reservoir level should be slightly larger at large incidence angles, but wave equation modelling shows that picking these reflections will not be easy, because of the presence of shear waves generated at upper interfaces. In-situ fracturation generates azimuthal anisotropy with velocity and amplitude variations with the propagation direction. These variations bear some information about the crack density, about the relation between the fracture nets and the porous medium, and about the fluid content in the pores and fractures. All these effects are however weak and their measurement requires careful seismic data acquisition and processing.
{"title":"Feasibility of Seismic Monitoring at a Potential CO2 Injection Test Site in the Paris Basin","authors":"M. Becquey, N. Lucet, F. Huguet","doi":"10.2516/OGST/2009033","DOIUrl":"https://doi.org/10.2516/OGST/2009033","url":null,"abstract":"Seismic effects of the injection of CO2 into a partially depleted oil field have been evaluated. Seismic modelling yields small time-lapse effects, including 0.4 ms time-shifts and 4 to 6% amplitude variations at the top and bottom of the reservoir. Amplitude variations at the reservoir level should be slightly larger at large incidence angles, but wave equation modelling shows that picking these reflections will not be easy, because of the presence of shear waves generated at upper interfaces. In-situ fracturation generates azimuthal anisotropy with velocity and amplitude variations with the propagation direction. These variations bear some information about the crack density, about the relation between the fracture nets and the porous medium, and about the fluid content in the pores and fractures. All these effects are however weak and their measurement requires careful seismic data acquisition and processing.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83728989","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
C. Chalbaud, M. Robin, J. Lombard, H. Bertin, P. Egermann
It has been long recognized that interfacial interactions (interfacial tension, wettability, capillarity and interfacial mass transfer) govern fluid distribution and behaviour in porous media. Therefore the interfacial interactions between CO2 , brine and reservoir oil and/or gas have an important influence on the effectiveness of any CO2 storage operation. There is a lack of experimental data related to interfacial properties for all the geological storage options (oil & gas reservoirs, coalbeds, deep saline aquifers). In the case of deep saline aquifers, there is a gap in data and knowledge of brine-CO2 interfacial properties at storage conditions. More specifically, experimental interfacial tension values and experimental tests in porous media are necessary to better understand the wettability evolution as a function of thermodynamic conditions and it’s effects on fluid flow in the porous media. In this paper, a complete set of experimental values of brine-CO2 Interfaciale Tension (IFT) at pressure, temperature and salt concentration conditions representative of those of a CO2 storage operation. A correlation is derived from experimental data published in a companion paper [Chalbaud C., Robin M., Lombard J.-M., Egermann P., Bertin H. (2009) Interfacial Tension Measurements and Wettability Evaluation for Geological CO2 Storage, Adv. Water Resour. 32, 1, 1-109] to model IFT values. This paper pays particular attention to coreflooding experiments showing that the CO2 partially wets the surface in a Intermediate-Wet (IW) or Oil-Wet (OW) limestone rock. This wetting behavior of CO2 is coherent with observations at the pore scale in glass micromodels and presents a negative impact on the storage capacity of a given site.
人们早就认识到，界面相互作用(界面张力、润湿性、毛细作用和界面传质)控制着多孔介质中的流体分布和行为。因此，CO2、卤水和储层油/气之间的界面相互作用对任何CO2储存作业的有效性都有重要影响。目前缺乏与所有地质存储选项(油气储层、煤层、深盐水含水层)的界面特性相关的实验数据。在深盐水含水层的情况下，在储存条件下的盐水-二氧化碳界面特性的数据和知识存在空白。更具体地说，为了更好地理解润湿性随热力学条件的变化及其对多孔介质中流体流动的影响，有必要进行实验界面张力值和实验测试。本文给出了一套完整的盐水-CO2界面张力(IFT)在压力、温度和盐浓度条件下的实验值，代表了一次CO2封存作业。相关性来自于发表在一篇配套论文中的实验数据[Chalbaud C.， Robin M.， Lombard J.-M.]。[3]张建军，张建军，张建军，等。(2009)基于地层学方法的地层学研究[j] .地球科学进展，32(1):1- 9。本文特别关注了岩心注水实验，表明CO2部分润湿了中湿(IW)或油湿(OW)石灰岩的表面。CO2的这种润湿行为与玻璃微观模型在孔隙尺度上的观察一致，并对给定地点的存储容量产生负面影响。
{"title":"Brine/CO2 Interfacial Properties and Effects on CO2 Storage in Deep Saline Aquifers","authors":"C. Chalbaud, M. Robin, J. Lombard, H. Bertin, P. Egermann","doi":"10.2516/OGST/2009061","DOIUrl":"https://doi.org/10.2516/OGST/2009061","url":null,"abstract":"It has been long recognized that interfacial interactions (interfacial tension, wettability, capillarity and interfacial mass transfer) govern fluid distribution and behaviour in porous media. Therefore the interfacial interactions between CO2 , brine and reservoir oil and/or gas have an important influence on the effectiveness of any CO2 storage operation. There is a lack of experimental data related to interfacial properties for all the geological storage options (oil & gas reservoirs, coalbeds, deep saline aquifers). In the case of deep saline aquifers, there is a gap in data and knowledge of brine-CO2 interfacial properties at storage conditions. More specifically, experimental interfacial tension values and experimental tests in porous media are necessary to better understand the wettability evolution as a function of thermodynamic conditions and it’s effects on fluid flow in the porous media. In this paper, a complete set of experimental values of brine-CO2 Interfaciale Tension (IFT) at pressure, temperature and salt concentration conditions representative of those of a CO2 storage operation. A correlation is derived from experimental data published in a companion paper [Chalbaud C., Robin M., Lombard J.-M., Egermann P., Bertin H. (2009) Interfacial Tension Measurements and Wettability Evaluation for Geological CO2 Storage, Adv. Water Resour. 32, 1, 1-109] to model IFT values. This paper pays particular attention to coreflooding experiments showing that the CO2 partially wets the surface in a Intermediate-Wet (IW) or Oil-Wet (OW) limestone rock. This wetting behavior of CO2 is coherent with observations at the pore scale in glass micromodels and presents a negative impact on the storage capacity of a given site.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80141479","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The developments and results presented in this paper are taken from the work carried out as part of the GeoCarbon-Monitoring project, which was partly funded by the French National Research Agency (ANR). An important part of this project covers methods for gas monitoring on the surface as well as within the cap rock of geological CO2 storage sites. The work undertaken by INERIS was targeted at two specific approaches which are often recommended as essential for the monitoring of future storage sites : early detection (pre-alert), based on the sampling and analysis of gas at the bottom of the dedicated boreholes which are drilled from the surface into the intermediate cap rock strata ; the detection and quantification of the gaseous flux of CO2 released from the ground into the atmosphere. These two approaches were developed in the laboratory successively and then applied and tested in-situ, under conditions that are as close as possible to those of the future storage sites. They offer the advantage of ensuring a direct measurement as well as providing real-time information on the presence or, on the contrary, the absence of CO2 leaks. The tests undertaken on a 200 meter deep borehole have shown that the detection of CO2 leaks passing through the intermediate overburden strata was possible thanks to the continuous sampling and analysis of the composition of the gas which accumulated at the bottom of the borehole. In particular, the detection of small releases of gas emanating from the surrounding rock gave rise to a number of good results. These releases may be a precursor to a larger leak. Likewise, it has been possible to take a sample and ensure the transit of gas over long distances, up to 1000 meters from the sampling point. This was done without causing any significant deformation or dilution of the initial gaseous signal, even for low amplitude leaks. These results allow us to envisage the implementation of a relatively simple system for detecting and monitoring gas leaks through intermediate cap rock strata. This system will largely comprise conventional industrial gas sensors which are available off the shelf. The direct measurement of gas flows emanating from the ground is one of the most effective ways to monitor a storage site. The INERIS accumulation chamber method has been improved to measure low and very low CO2 flux rates. It can now be used to measure a wide range of CO2 flux rates, from very low emission levels of 0.05 to 0.2 cm3.min-1.m-2 up to extremely high flux rates of some 3000 cm3.min-1.m-2. The accuracy and operational characteristics of chamber method have been checked and validated by tests performed in a laboratory and on a test rig, as well as through field measurements taken under real conditions at sites that naturally release CO2. These tests have shown that the method has reached full technical maturity and that it can be applied on a practical level to detect and monitor CO2 and methane emissions on the ground's
{"title":"Development of Methods for Gaseous Phase Geochemical Monitoring on the Surface and in the Intermediate Overburden Strata of Geological CO2 Storage Sites","authors":"Z. Pokryszka, A. Charmoille, G. Bentivegna","doi":"10.2516/OGST/2009084","DOIUrl":"https://doi.org/10.2516/OGST/2009084","url":null,"abstract":"The developments and results presented in this paper are taken from the work carried out as part of the GeoCarbon-Monitoring project, which was partly funded by the French National Research Agency (ANR). An important part of this project covers methods for gas monitoring on the surface as well as within the cap rock of geological CO2 storage sites. The work undertaken by INERIS was targeted at two specific approaches which are often recommended as essential for the monitoring of future storage sites : early detection (pre-alert), based on the sampling and analysis of gas at the bottom of the dedicated boreholes which are drilled from the surface into the intermediate cap rock strata ; the detection and quantification of the gaseous flux of CO2 released from the ground into the atmosphere. These two approaches were developed in the laboratory successively and then applied and tested in-situ, under conditions that are as close as possible to those of the future storage sites. They offer the advantage of ensuring a direct measurement as well as providing real-time information on the presence or, on the contrary, the absence of CO2 leaks. The tests undertaken on a 200 meter deep borehole have shown that the detection of CO2 leaks passing through the intermediate overburden strata was possible thanks to the continuous sampling and analysis of the composition of the gas which accumulated at the bottom of the borehole. In particular, the detection of small releases of gas emanating from the surrounding rock gave rise to a number of good results. These releases may be a precursor to a larger leak. Likewise, it has been possible to take a sample and ensure the transit of gas over long distances, up to 1000 meters from the sampling point. This was done without causing any significant deformation or dilution of the initial gaseous signal, even for low amplitude leaks. These results allow us to envisage the implementation of a relatively simple system for detecting and monitoring gas leaks through intermediate cap rock strata. This system will largely comprise conventional industrial gas sensors which are available off the shelf. The direct measurement of gas flows emanating from the ground is one of the most effective ways to monitor a storage site. The INERIS accumulation chamber method has been improved to measure low and very low CO2 flux rates. It can now be used to measure a wide range of CO2 flux rates, from very low emission levels of 0.05 to 0.2 cm3.min-1.m-2 up to extremely high flux rates of some 3000 cm3.min-1.m-2. The accuracy and operational characteristics of chamber method have been checked and validated by tests performed in a laboratory and on a test rig, as well as through field measurements taken under real conditions at sites that naturally release CO2. These tests have shown that the method has reached full technical maturity and that it can be applied on a practical level to detect and monitor CO2 and methane emissions on the ground's ","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80829451","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Préambule : Le stockage du CO2 au service de la lutte contre le changement climatique - Étude de sites géologiques dans le bassin Parisien, France","authors":"J. Lecourtier","doi":"10.2516/OGST/2010011","DOIUrl":"https://doi.org/10.2516/OGST/2010011","url":null,"abstract":"","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76032615","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
H. Fabriol, M. Becquey, Frédéric Huguet, M. Lescanne, Gérard, Mouronval, J. Pironon, Zbigniew Pokryzska
The aim of the Geocarbone-Monitoring research project was the evaluation and testing, as far as possible, of the different monitoring methods that might be applied in the specific context of the Paris Basin. Their main objectives are to: detect and map CO2 in the reservoir rocks; detect and quantify possible leaks between the reservoir and the surface. The partners developed several thoughts and research concerning the various monitoring methods. This enabled drawing up a critical overview of existing methods and proposing leads for further work. At the end of the project, recommendations were made for the stakeholders of CO2 storage, i.e. the government departments regulating storage, decision-makers, and future site operators. In addition, a proposal was made for the general design and implementation of a monitoring programme of an injection test in the Paris Basin, within a depleted reservoir or a deep aquifer.
{"title":"The Géocarbone-Monitoring Project: Main Results and Recommendations for Monitoring Deep Geological CO2 Storage in the Paris Basin","authors":"H. Fabriol, M. Becquey, Frédéric Huguet, M. Lescanne, Gérard, Mouronval, J. Pironon, Zbigniew Pokryzska","doi":"10.2516/OGST/2010003","DOIUrl":"https://doi.org/10.2516/OGST/2010003","url":null,"abstract":"The aim of the Geocarbone-Monitoring research project was the evaluation and testing, as far as possible, of the different monitoring methods that might be applied in the specific context of the Paris Basin. Their main objectives are to: detect and map CO2 in the reservoir rocks; detect and quantify possible leaks between the reservoir and the surface. The partners developed several thoughts and research concerning the various monitoring methods. This enabled drawing up a critical overview of existing methods and proposing leads for further work. At the end of the project, recommendations were made for the stakeholders of CO2 storage, i.e. the government departments regulating storage, decision-makers, and future site operators. In addition, a proposal was made for the general design and implementation of a monitoring programme of an injection test in the Paris Basin, within a depleted reservoir or a deep aquifer.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84546952","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Since 2005, the French National Research Agency supports several scientific projects intended to select, validate and implement a geological site for CO2 storage in France. The work presented in this paper was carried out within the Geocarbone-Injectivity project, aimed to study the suitability of a carbonate deep saline aquifer located in the Paris basin for a geological CO2 storage. A geological analog to the aquifer rock was chosen in order to perform several petrophysical and transport characterizations. Measured parameters were intrinsic permeability, inertia coefficient, Klinkenberg coefficient, relative permeabilities and transport properties such as the dispersion coefficient and the stratification factor. Samples of Lavoux limestone were characterized in their original state and also after a phase of CO2 -like acid-rock alteration. Results show sensible changes in porosity, permeability and inertia coefficient and almost no change in relative permeabilities, dispersion coefficient and stratification coefficient. These results mean that the CO2 injectivity would be maintained and even enhanced during its injection in the considered Dogger formation. Nevertheless, to confirm this observation, additional experimental and modeling work should be performed, taking into account the potential fine migration. A permeability alteration could be expected due to these fine displacements.
{"title":"Transport Properties of Lavoux Limestone at Various Stages of CO2-Like Acid-Rock Alteration","authors":"G. Radilla, M. Kacem, J. Lombard, M. Fourar","doi":"10.2516/OGST/2009081","DOIUrl":"https://doi.org/10.2516/OGST/2009081","url":null,"abstract":"Since 2005, the French National Research Agency supports several scientific projects intended to select, validate and implement a geological site for CO2 storage in France. The work presented in this paper was carried out within the Geocarbone-Injectivity project, aimed to study the suitability of a carbonate deep saline aquifer located in the Paris basin for a geological CO2 storage. A geological analog to the aquifer rock was chosen in order to perform several petrophysical and transport characterizations. Measured parameters were intrinsic permeability, inertia coefficient, Klinkenberg coefficient, relative permeabilities and transport properties such as the dispersion coefficient and the stratification factor. Samples of Lavoux limestone were characterized in their original state and also after a phase of CO2 -like acid-rock alteration. Results show sensible changes in porosity, permeability and inertia coefficient and almost no change in relative permeabilities, dispersion coefficient and stratification coefficient. These results mean that the CO2 injectivity would be maintained and even enhanced during its injection in the considered Dogger formation. Nevertheless, to confirm this observation, additional experimental and modeling work should be performed, taking into account the potential fine migration. A permeability alteration could be expected due to these fine displacements.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77785175","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
F. Gal, K. L. Pierrès, M. Brach, Gilles Braibant, C. Bény, A. Battani, E. Tocqué, Y. Benoit, E. Jeandel, Z. Pokryszka, A. Charmoille, G. Bentivegna, J. Pironon, P. Donato, C. Garnier, C. Cailteau, O. Barrès, G. Radilla, A. Bauer
One of the options considered to mitigate greenhouse gas concentrations in the atmosphere is underground storage of CO2 . There is a strong need for enhancing and developing methods that would help throughout the duration life of such underground storage, to ensure the safety and able to monitor the evolution of the injected CO2 plume. Among these, geochemical methods can play an important role. Here, we describe results acquired under the research programme “Geocarbone-Monitoring”, partially funded by the French National Research Agency, on the Montmiral natural analogue in South-Eastern France. Other results obtained under the same research programme in the French Massif Central are reported elsewhere in this volume.Spot sampling methods allowing a great geographical coverage and continuous measurements on selected points were undertaken in 2006 and 2007, in order to determine soil gas concentrations and fluxes as well as carbon isotope ratio determinations. One important result is that without any evidence of deep CO2 leakage, both CO2 concentrations and fluxes appear to be higher than can be explained only by biological activities. Further investigations are thus needed to understand the gas evolution better throughout the year.
{"title":"Surface Gas Geochemistry above the Natural CO2 Reservoir of Montmiral (Drôme, France), Source Tracking and Gas Exchange between the Soil, Biosphere and Atmosphere","authors":"F. Gal, K. L. Pierrès, M. Brach, Gilles Braibant, C. Bény, A. Battani, E. Tocqué, Y. Benoit, E. Jeandel, Z. Pokryszka, A. Charmoille, G. Bentivegna, J. Pironon, P. Donato, C. Garnier, C. Cailteau, O. Barrès, G. Radilla, A. Bauer","doi":"10.2516/OGST/2009068","DOIUrl":"https://doi.org/10.2516/OGST/2009068","url":null,"abstract":"One of the options considered to mitigate greenhouse gas concentrations in the atmosphere is underground storage of CO2 . There is a strong need for enhancing and developing methods that would help throughout the duration life of such underground storage, to ensure the safety and able to monitor the evolution of the injected CO2 plume. Among these, geochemical methods can play an important role. Here, we describe results acquired under the research programme “Geocarbone-Monitoring”, partially funded by the French National Research Agency, on the Montmiral natural analogue in South-Eastern France. Other results obtained under the same research programme in the French Massif Central are reported elsewhere in this volume.Spot sampling methods allowing a great geographical coverage and continuous measurements on selected points were undertaken in 2006 and 2007, in order to determine soil gas concentrations and fluxes as well as carbon isotope ratio determinations. One important result is that without any evidence of deep CO2 leakage, both CO2 concentrations and fluxes appear to be higher than can be explained only by biological activities. Further investigations are thus needed to understand the gas evolution better throughout the year.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90397811","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Injection of carbon dioxide (CO2 ) underground, for long-term geological storage purposes, is considered as an economically viable option to reduce greenhouse gas emissions in the atmosphere. The chemical interactions between supercritical CO2 and the potential reservoir rock need to be thoroughly investigated under thermodynamic conditions relevant for geological storage. In the present study, 40 samples of Lavoux limestone and Adamswiller sandstone, both collected from reservoir rocks in the Paris basin, were experimentally exposed to CO2 in laboratory autoclaves specially built to simulate CO2 -storage-reservoir conditions. The two types of rock were exposed to wet supercritical CO2 and CO2 -saturated water for one month, at 28 MPa and 90°C, corresponding to conditions for a burial depth approximating 3 km. The changes in mineralogy and microtexture of the samples were measured using X-ray diffraction analyses, Raman spectroscopy, scanning-electron microscopy, and energy-dispersionspectroscopy microanalysis. The petrophysical properties were monitored by measuring the weight, density, mechanical properties, permeability, global porosity, and local porosity gradients through the samples. Both rocks maintained their mechanical and mineralogical properties after CO2 exposure despite an increase of porosity and permeability. Microscopic zones of calcite dissolution observed in the limestone are more likely to be responsible for such increase. In the sandstone, an alteration of the petrofabric is assumed to have occurred due to clay minerals reacting with CO2 . All samples of Lavoux limestone and Adamswiller sandstone showed a measurable alteration when immersed either in wet supercritical CO2 or in CO2 -saturated water. These batch experiments were performed using distilled water and thus simulate more severe conditions than using formation water (brine).
{"title":"Evolution of the Petrophysical and Mineralogical Properties of Two Reservoir Rocks Under Thermodynamic Conditions Relevant for CO2 Geological Storage at 3 km Depth","authors":"G. Rimmelé, V. Barlet-Gouedard, François Renard","doi":"10.2516/OGST/2009071","DOIUrl":"https://doi.org/10.2516/OGST/2009071","url":null,"abstract":"Injection of carbon dioxide (CO2 ) underground, for long-term geological storage purposes, is considered as an economically viable option to reduce greenhouse gas emissions in the atmosphere. The chemical interactions between supercritical CO2 and the potential reservoir rock need to be thoroughly investigated under thermodynamic conditions relevant for geological storage. In the present study, 40 samples of Lavoux limestone and Adamswiller sandstone, both collected from reservoir rocks in the Paris basin, were experimentally exposed to CO2 in laboratory autoclaves specially built to simulate CO2 -storage-reservoir conditions. The two types of rock were exposed to wet supercritical CO2 and CO2 -saturated water for one month, at 28 MPa and 90°C, corresponding to conditions for a burial depth approximating 3 km. The changes in mineralogy and microtexture of the samples were measured using X-ray diffraction analyses, Raman spectroscopy, scanning-electron microscopy, and energy-dispersionspectroscopy microanalysis. The petrophysical properties were monitored by measuring the weight, density, mechanical properties, permeability, global porosity, and local porosity gradients through the samples. Both rocks maintained their mechanical and mineralogical properties after CO2 exposure despite an increase of porosity and permeability. Microscopic zones of calcite dissolution observed in the limestone are more likely to be responsible for such increase. In the sandstone, an alteration of the petrofabric is assumed to have occurred due to clay minerals reacting with CO2 . All samples of Lavoux limestone and Adamswiller sandstone showed a measurable alteration when immersed either in wet supercritical CO2 or in CO2 -saturated water. These batch experiments were performed using distilled water and thus simulate more severe conditions than using formation water (brine).","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80617323","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
J. Lombard, M. Azaroual, J. Pironon, D. Broseta, P. Egermann, Gilles Munier, G. Mouronval
The objective of the GeoCarbone-Injectivity project was to develop a methodology to study the complex phenomena involved in the near wellbore region during CO2 injection. This paper presents an overview of the program and results of the project, and some further necessary developments. The proposed methodology is based on experiments and simulations at the core scale, in order to understand (physical modelling and definition of constitutive laws) and quantify (calibration of simulation tools) the mechanisms involved in injectivity variations: fluid/rock interactions, transport mechanisms, geomechanical effects. These mechanisms and the associated parameters have then to be integrated in the models at the wellbore scale. The methodology has been applied for the study of a potential injection of CO2 in the Dogger geological formation of the Paris Basin, in collaboration with the other ANR GeoCarbone projects.
{"title":"CO2 Injectivity in Geological Storages: an Overview of Program and Results of the GeoCarbone-Injectivity Project","authors":"J. Lombard, M. Azaroual, J. Pironon, D. Broseta, P. Egermann, Gilles Munier, G. Mouronval","doi":"10.2516/OGST/2010013","DOIUrl":"https://doi.org/10.2516/OGST/2010013","url":null,"abstract":"The objective of the GeoCarbone-Injectivity project was to develop a methodology to study the complex phenomena involved in the near wellbore region during CO2 injection. This paper presents an overview of the program and results of the project, and some further necessary developments. The proposed methodology is based on experiments and simulations at the core scale, in order to understand (physical modelling and definition of constitutive laws) and quantify (calibration of simulation tools) the mechanisms involved in injectivity variations: fluid/rock interactions, transport mechanisms, geomechanical effects. These mechanisms and the associated parameters have then to be integrated in the models at the wellbore scale. The methodology has been applied for the study of a potential injection of CO2 in the Dogger geological formation of the Paris Basin, in collaboration with the other ANR GeoCarbone projects.","PeriodicalId":19444,"journal":{"name":"Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2010-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90590990","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：