A recent concern is the cause and effect of global climate change. Many institutions give credit for these changes to the increased levels of greenhouse gases in the atmosphere, in particular the increase in the amount of carbon dioxide present. There is a growing interest in carbon capture and storage (CCS) as a means to reduce the global impact of CO₂ on the climate as a greenhouse gas. Carbon capture is the process of removing CO₂ from the atmosphere as well as preventing it from entering the atmosphere by means of exhaust. The captured carbon is stored underground in reservoirs. These reservoirs have the storage space to handle the volume of CO₂ injected as well as a caprock layer preventing the injection fluid from returning to the surface. Additionally, CO₂ can be used for enhanced oil recovery (EOR). To monitor the injection sites used for the CO₂ storage or EOR process, the integrity of the caprock as well as the surrounding rock formations are the locations of interest. Knowing when a joint or a fracture is going to slip is necessary to prevent major failures within geologic strata. It is necessary to prevent these slips from occurring to retain the integrity of the caprock, which is keeping the fluid within the reservoirs. Passive acoustic emissions monitoring was used to determine how effectively failure locations could be located in three unique tests. Coupled with double difference tomography, the failure of a Berea Sandstone sample and Marcellus Shale sample were calculated to determine how well the stress redistribution within the sample could be mapped using the recorded data. For the main indenter tests two samples were tested, a piece of Berea Sandstone and a piece of Marcellus Shale. The secondary test was a transform shear test using sandstone, and the third test for caprock upheaval test attempted to recreate the failure of caprock due to injection pressure. For all tests, the samples were monitored using acoustic emissions software until failure or it was deduced that the test would not produce failure. The secondary tests did not progress through the data analysis as far as the indentation tests, however valuable information was gathered from these tests. The shear test demonstrated the effectiveness of the passive acoustic emissions monitoring system to record shear failure. This test provides confidence in this technology to record and located events that are not occurring in compression. The caprock upheaval tests were not successful in causing failure in the caprock, however during the testing the passive acoustic emissions monitoring system was able record and locate events that occurred within the sample around the boundary on the reservoir. At the reservoir boundaries there was evidence of fluid flowing through the reservoir, and the events align with these locations. This positive result shows that the monitoring system is able to locate events induced by fluid injection. The results of these tests provide confidence in the passive acoustic emissions monitoring system to record accurate data for the caprock integrity monitoring. The tomograms created from the recorded data accurately imaged the areas of interest within the rock samples. From these results, passive acoustic emissions monitoring systems coupled with double difference tomography has proven capable of monitoring homogeneous samples within a laboratory environment. With further testing, this technology could possibly be a viable option for monitoring carbon sequestration sites. / Master of Science

To safely store carbon dioxide in enhanced oil recovery/ CO2 sequestration projects it is important to ensure the integrity of the caprock during and after production and injection. A change in fluid pressure and temperature within a porous reservoir will generally induce stress changes within the reservoir and the rocks that surround it. Amongst the potential hazards resulting from these induced stress changes is the reactivation of existing faults or fractures and inducing new fractures, which may breach the hydraulic integrity of the caprock that bounds the reservoir.<p> The theories of inclusions and inhomogeneities have been used in this research to derive semi-analytical and closed-form solutions for induced stress change during pore pressure change within a reservoir and in the surrounding rock, under plane strain and axisymmetric conditions. Methods have been developed to assess fault reactivation and induced fracturing during injection or production within a reservoir. The failure stress change concept for a Coulomb failure criterion has been used to study the likelihood of fault reactivation and induced fracturing within the reservoir. Formulations have been adopted to calculate the critical pressure change for fault reactivation and induced fracturing within the reservoir and in the surrounding rock during injection and production. Sensitivity analysis has been performed to study the effects of different parameters such as initial in-situ stress, reservoir geometry, reservoir depth, reservoir tilt or dip , material property contrast between the reservoir and surrounding rock, fault geometry, fault strength, and intact rock strength. General patterns of induced stress change, in-situ stress evolution, fault reactivation, and induced fracturing have been identified.<p> The developed methodologies have been applied to six different case studies: fault reactivation analysis in the entire field for a synthetic case study; induced fracturing analysis in the entire field in a synthetic case study; fault reactivation and induced stress change analysis within the Ekofisk oil reservoir in North Sea; fault reactivation analysis in the Lacq gas reservoir in France; the Weyburn-Midale EOR/CO2 Storage project in southeast Saskatchewan; and acid gas injection in Zama oil field, Alberta. The results of these case studies show good consistency with field observation, and physical and numerical models.<p> The generality, simplicity, and straightforwardness of the developed methodologies, along with their flexibility to model different plausible scenarios and their ease of implementation for systematic sensitivity analyses makes them suitable for decision-making and uncertainty management, specifically in early stages of reservoir development or site assessment for geological sequestration of carbon dioxide.

To safely store carbon dioxide in enhanced oil recovery/ CO2 sequestration projects it is important to ensure the integrity of the caprock during and after production and injection. A change in fluid pressure and temperature within a porous reservoir will generally induce stress changes within the reservoir and the rocks that surround it. Amongst the potential hazards resulting from these induced stress changes is the reactivation of existing faults or fractures and inducing new fractures, which may breach the hydraulic integrity of the caprock that bounds the reservoir.<p> The theories of inclusions and inhomogeneities have been used in this research to derive semi-analytical and closed-form solutions for induced stress change during pore pressure change within a reservoir and in the surrounding rock, under plane strain and axisymmetric conditions. Methods have been developed to assess fault reactivation and induced fracturing during injection or production within a reservoir. The failure stress change concept for a Coulomb failure criterion has been used to study the likelihood of fault reactivation and induced fracturing within the reservoir. Formulations have been adopted to calculate the critical pressure change for fault reactivation and induced fracturing within the reservoir and in the surrounding rock during injection and production. Sensitivity analysis has been performed to study the effects of different parameters such as initial in-situ stress, reservoir geometry, reservoir depth, reservoir tilt or dip , material property contrast between the reservoir and surrounding rock, fault geometry, fault strength, and intact rock strength. General patterns of induced stress change, in-situ stress evolution, fault reactivation, and induced fracturing have been identified.<p> The developed methodologies have been applied to six different case studies: fault reactivation analysis in the entire field for a synthetic case study; induced fracturing analysis in the entire field in a synthetic case study; fault reactivation and induced stress change analysis within the Ekofisk oil reservoir in North Sea; fault reactivation analysis in the Lacq gas reservoir in France; the Weyburn-Midale EOR/CO2 Storage project in southeast Saskatchewan; and acid gas injection in Zama oil field, Alberta. The results of these case studies show good consistency with field observation, and physical and numerical models.<p> The generality, simplicity, and straightforwardness of the developed methodologies, along with their flexibility to model different plausible scenarios and their ease of implementation for systematic sensitivity analyses makes them suitable for decision-making and uncertainty management, specifically in early stages of reservoir development or site assessment for geological sequestration of carbon dioxide.

L’augmentation constante du dioxyde de carbone dans l’atmosphère est considérée comme étant la cause principale du réchauffement climatique actuel. La séquestration géologique du CO2 semble être une des meilleures solutions envisageable pour réduire les rejets des gaz à effet de serre (dont le CO2) dans l’atmosphère, seulement si l’intégrité de la couverture du réservoir est préservée sur des centaines ou des milliers d’années. Des simulations expérimentales en batch ont été réalisées afin d’observer la réactivité d’une roche de couverture argileuse et d’une roche réservoir carbonatée en présence de CO2 à 80°C et 150°C pour une pression de 150 bar avec une eau équilibrée. Le protocole analytique mis en place a permis de comparer les roches avant et après expérimentation concluant à une réactivité très faible, centrée sur l’aluminium au niveau des phyllosilicates. Les analyses texturales montrent que le CO2 n’a pas d’incidence sur les propriétés d’adsorption et sur la surface spécifique. L’étude des carbonates du réservoir par la microscopie confocale a permis de mettre en évidence des phénomènes de dissolution-précipitation qui n’ont cependant pas d’impact important sur la chimie et la structure du réservoir. Les simulations numériques réalisées sur des minéraux de référence comme la montmorillonite calcique ou le clinochlore montrent une réactivité importante en présence de CO2 non atteinte expérimentalement, certainement due à des lacunes dans les bases de données thermodynamiques ou à la cinétique des réactions. Les simulations sur Bure ne montrent pas de réactivité sur les minéraux majeurs de la marne argileuse confirmant les résultats obtenus en expérimentation batch / The constant increase in the quantity of carbon dioxide in the atmosphere is regarded as being the principal cause of the current global warming. The geological sequestration of CO2 seems to be an ideal solution to reduce the increase of greenhouse gases (of which CO2) in the atmosphere but only if the reservoir’s caprock keep its integrity for several hundreds or thousands of years. Batch experimental simulations were conducted to observe the reactivity of a caprock made of clay and a carbonate reservoir with CO2 at 80°C and 150°C for a pressure of 150 bar with an equilibrated water. The analytical protocol established allowed to compare the rocks before and after experimentations finding a very low reactivity, focusing on aluminium in phyllosilicates. Textural analysis shows that CO2 does not affect the properties of adsorption and the specific surface. The study of carbonate reservoir by confocal microscopy has revealed phenomena of dissolution-precipitation which have no significant impact on chemistry and structure of the reservoir. The numerical simulations carried out on mineral reference as calcium montmorillonite or clinochlore show a significant reaction in the presence of CO2 not achieved experimentally, probably due to lacunas in the thermodynamic databases or the kinetics of reactions. The simulations on Bure show no reaction on the major minerals confirming the results with batch experiments

Dans le cadre du stockage géologique de gaz acides, il est impératif de garantir l'intégrité des matériaux sollicités afin d'assurer un confinement pérenne du fluide injecté. Le but de ce travail de thèse est d'étudier, par le biais de modélisations expérimentales, les phénomènes pouvant être responsables de la déstabilisation du système et qui peuvent conduire à des fuites du gaz stocké. Le premier modèle expérimental, appelé COTAGES a permis d'étudier les effets de la déstabilisation thermique provoquée par l'injection d'un gaz à température ambiante dans un réservoir chaud. Ce dispositif a permis de mettre en évidence un transfert de matière important depuis la zone froide (30°C) vers la zone chaude (100°C) conduisant à des modifications des propriétés pétrophysiques. Ces résultats soulignent l'importance de la température d'injection sur la conservation des propriétés d'injectivité du système. Le second modèle, appelé "Sandwich" a permis d'étudier le comportement de l?interface entre la roche couverture (argilite COX) et le ciment de puits. Les expériences batch du modèle Sandwich en présence de CO2 ont permis de mettre en évidence une fracturation de l'interface provoquée par la carbonatation précoce du ciment. Ces résultats soulignent l'importance de l'état initial de la roche couverture dans la séquestration du fluide injecté. Le troisième modèle expérimental est le modèle MIRAGES. Ce dispositif innovant permet d'injecter en continu un flux de CO2 dans un échantillon. Les résultats ont mis en évidence un colmatage partiel de la porosité inter-oolithe à proximité du puits d'injection, ainsi qu'une carbonatation du ciment sous la forme d'un assemblage calcite/aragonite / In the framework of the CO2 storage, it is crucial to ensure the integrity of the solicited materials in order to guarantee the permanent confinement of the sequestrated fluids. Using experimental simulation the purpose of this work is to study the mechanisms which could be responsible for the system destabilization and could lead CO2 leakage from the injection well. The first experimental model, called COTAGES allows studying the effects of the thermal destabilisation caused by the injection of a fluid at 25°C in a hotter reservoir (submitted to the geothermal gradient). This device allows demonstrating an important matter transfer from the cold area (30°C) toward the hot area (100°C). These results highlight the importance of the injection temperature on the injectivity properties and on the possible petrophysical evolutions of the near well. The second model, called ?Sandwich?, allow studying the behaviour of the interface between caprock (COX argillite) and well cement. Indeed, interfaces between the different rock and the well materials represent a weakness area (differential reactivity, fracturing?). Batch experiments carried out with this device in presence of CO2 show the fracturing of the interface caused by the early carbonation of the cement. The third experimental model, called MIRAGES is an innovative device which allows injecting continuously CO2 in a core sample. Samples made of Lavoux limestone and well cement reproduce the injection well at 1/20 scale. Results show a partial filling of the inter-oolithic porosity close to the injection well, and also the carbonation of the cement according to an assemblage of calcite/aragonite

Une solution prometteuse pour diminuer les émissions anthropogéniques de gaz à effet de serre consiste à injecter une partie des rejets industriels de CO2 dans des formations souterraines. Celles-ci comportent un réservoir entouré de roches de couverture, qui constituent la première barrière à la migration des fluides. La caractérisation de leurs propriétés de confinement et de leur évolution en présence de CO2 est donc un élément clé de la sécurité d’un site de stockage. Le travail présenté propose une méthodologie, appliquée ici à des roches carbonatées du bassin parisien, permettant de mesurer les paramètres de transport de roches de couverture et les conséquences d’un vieillissement en conditions représentatives de celles d’un stockage en aquifère profond. La pression de percée, le coefficient de diffusion des produits de dissolution du CO2, et la perméabilité, paramètres contrôlant les principaux mécanismes de fuite, ont été mesurés avant et après altération des matériaux par réaction avec une saumure saturée en CO2 dans des conditions thermodynamiques typiques d’un réservoir (environ 80°C et 100 bar). Les résultats obtenus ont révélé un bon comportement global des roches, mais également une forte diminution du potentiel de confinement en présence de défauts structurels initiaux (fractures rebouchées, pores de grand diamètre...). Une simulation numérique décrivant les évolutions de la formation rocheuse non-fissurée sur une durée de 1000 ans a été réalisée en s’appuyant sur des paramètres mesurés directement ou obtenus par modélisation des essais d’altération. Elle a montré que les transformations engendrées par le stockage de CO2 sous une roche de couverture homogène restent très limitées spatialement / A promising solution to reduce anthropogenic emissions of greenhouse effect gases consists in the injection and long-term storage of a part of the industrial carbon dioxide discharges in underground formations. These formations must be composed of a reservoir surrounded by tight caprocks, which represent the first barrier preventing fluids migration. The characterization of their confining properties and of their evolution in presence of CO2 is thus a key element regarding a storage site security. This work presents a methodology allowing the measurement of caprocks transport parameters and the consequences of an alteration under representative conditions of deep aquifers storage. This methodology was applied to carbonate rocks from the Paris basin. The breakthrough pressure, the diffusion coefficient of CO2 dissolution products, and the permeability, controlling parameters of leakage mechanisms, were measured before and after alteration of the materials by reaction with a CO2-saturated brine under reservoir thermodynamic conditions (about 80°C and 100 bar). Results revealed a satisfactory global behaviour under these aggressive conditions, but also a strong diminution of the confinement potential in presence of initial structural faults (sealed fractures, large-diameter pores…) forming higher-permeability zones. A numeric simulation describing the evolution of a homogeneous rock formation during 1000 years was also realized based on parameters directly measured or obtained by modelling of the alteration experiments. It showed that the transformations brought by the CO2 storage under a rock formation with no initial faults remain very localized spatially