Chalbaud, Carlos (2007) CO2 interfacial properties : application to multiphase flow at reservoir conditions. PhD thesis Mécanique, ENSAM 2007ENAM0009 p.228.

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Abstract

In this work we deal with the interfacial properties of CO2 at reservoir conditions with a special interest on deep saline aquifers. Each chapter of this dissertation represents a different physical scale studied with different experimental devices and simulation tools. The results obtained in the first part of this study represent a complete data set of brine-CO2 interfacial tension at reservoir conditions. A semi-analytical equation is proposed in order to facilitate the work of reservoir engineers. The second deals with the interfacial properties at the pore scale using glass micromodels at different wettability conditions. This part shows the wetting behavior of CO2 on hydrophobic or oil-wet solid surfaces. A pore network model was used for the interpretation and exploitation of these results. The third part corresponds to two different experimental approaches at the core scale at different wettability conditions associated to a modelling at the Darcy scale. This part is a significant contribution to the validation of COORES compositional reservoir simulator developed by IFP. It has also allow us to estimate multiphase properties, Pc and kr, for brine-CO2 systems at reservoir conditions. This study presents the necessary scales to model CO2 storage in deep saline aquifers

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Table of content

INTRODUCTION 23

I.1 PROBLÉMATIQUE GÉNÉRALE: LE STOCKAGE GÉOLOGIQUE DU CO2 23

i.1.1 Réservoirs de brut 25

i.1.2 Réservoirs de gaz 25

i.1.3 Aquifères profonds 26

i.1.4 CO2 supercritique 27

I.2 PROBLÉMATIQUE ET OBJECTIFS DE LA THÈSE 30

I.3 DESCRIPTIF DU RAPPORT 31

1 TENSIONS INTERFACIALES SAUMURE-CO2 33

1.1 INTRODUCTION 35

1.1.1 ÉNERGIE LIBRE DE SURFACE ET TENSION SUPERFICIELLE 36

1.1.2 Adsorption 38

1.1.3 Interfaces courbes 39

1.2 BIBLIOGRAPHIE 40

1.2.1 Méthodes de mesure de la tension interfaciale 40

1.2.2 Tension interfaciale eau pure – CO2 44

1.2.3 Tension interfaciale saumure – CO2 46

1.3 MATÉRIELS ET MÉTHODES EXPÉRIMENTALES 48

1.3.1 Caractérisation des fluides 48

1.3.2 Dispositif expérimental 49

1.3.3 Protocole expérimental 51

1.4 RÉSULTATS ET DISCUSSIONS 54

1.4.1 Effets de la pression et de la température 54

1.4.2 Effets de la salinité 61

1.5 POSSIBLES IMPLICATIONS SUR LE STOCKAGE GÉOLOGIQUE 63

1.6 MODÉLISATION DE LA TENSION INTERFACIALE 66

1.6.1 La corrélation de Hebach et al. (2002) 66

1.6.2 La méthode du gradient linéaire 67

1.6.3 Le modèle du Parachor 68

1.6.4 La corrélation de Firoozabadi & Ramey (1988) 69

1.6.5 La corrélation de Chalbaud et al. (2006) 70

1.7 CONCLUSIONS 73

2 UTILISATION DES MICROMODÈLES À MOUILLABILITÉ CONTRÔLÉE POUR UNE ÉTUDE QUALITATIVE DE LA DISTRIBUTION DES FLUIDES (EAU/CO2) EN MILIEU POREUX 75

2.1 INTRODUCTION 77

2.1.1 Énergie de cohésion 77

2.1.2 Étalement sur un substrat fluide 77

2.1.3 Étalement sur un substrat solide (Mouillage). 79

2.1.4 La mouillabilité en milieux poreux 81

2.1.5 Altération de la mouillabilité d'une surface 82

2.2 BIBLIOGRAPHIE 84

2.2.1 Historique et construction des micromodèles 84

2.2.2 Mouillabilité et distribution des fluides dans le milieu poreux 84

2.2.3 Micromodèles à l’IFP 87

2.2.4 Procédés d’injection de CO2 ou d'autres gaz dans des milieux models 89

2.2.5 Théorie DLVO (Derjaguin & Landau, 1941 et Verwey & Overbeek , 1948) 91

2.3 MATÉRIEL ET MÉTHODES EXPÉRIMENTALES 97

2.3.1 Caractérisation des fluides 97

2.3.2 Fabrication des micromodèles (Robin et Shaïek, 2006) 97

2.3.3 Altération de la mouillabilité des micromodèles 104

2.3.4 Dispositif expérimental (Robin et Shaïek, 2006) 106

2.3.5 Protocole expérimental 109

2.4 RÉSULTATS ET DISCUSSIONS 110

2.4.1 Milieux mouillables à l'eau 118

2.4.2 Milieux mouillables à l'huile et de mouillabilité intermédiaire 119

2.5 CONCLUSIONS 120

3 ÉCOULEMENT DU CO2 EN MILIEUX POREUX: PROPRIÉTÉS CAPILLAIRES ET PERMÉABILITÉS RELATIVES 123

3.1 INTRODUCTION 125

3.1.1 Pourquoi est-il nécessaire de modéliser les opérations de stockage du CO2? 125

3.1.2 Mesures des propriétés pétrophysiques 126

3.1.3 Le principe des mesures par rayons X 127

3.1.4 Interprétation des expériences 128

3.1.5 Études antérieures de modélisation de l'injection du CO2 en milieu poreux 131

3.2 MATÉRIEL ET MÉTHODES EXPÉRIMENTALES 132

3.2.1 Nature des échantillons de roche et des fluides utilisés 132

3.2.2 Dispositifs expérimentaux 134

3.2.3 Protocoles expérimentaux 137

3.3 EXPÉRIENCES ET INTERPRÉTATIONS NUMÉRIQUES 138

3.3.1 Conditions opératoires des expériences 138

3.3.2 Traitement des résultats expérimentaux 139

3.3.3 Descriptif du simulateur utilisé 140

3.4 RÉSULTATS ET DISCUSSIONS 142

3.4.1 Efficacité du déplacement et paramétrisation du modèle 142

3.4.2 Calage historique des expériences 145

3.4.3 Estimation des propriétés pétrophysiques à partir des mesures locales : Pc et kr 151

3.5 CONCLUSIONS 163

4 ÉTUDE NUMÉRIQUE DE L'INFLUENCE DE LA MOUILLABILITÉ SUR LE STOCKAGE DE CO2 167

4.1 INTRODUCTION 169

4.1.1 Modélisation par réseaux de pores (de l'anglais Pore Network Modeling, PNM) 169

4.1.2 Notre approche 170

4.2 ÉCHELLE DE L' ÉCHANTILLON 173

4.3 ÉCHELLE DU RÉSERVOIR 177

4.4 CONCLUSIONS 185

5 CONCLUSIONS ET PERSPECTIVES 187

5.1 PRINCIPAUX RÉSULTATS OBTENUS. 189

5.2 ORIGINALITÉ ET CONTRIBUTION SCIENTIFIQUE. 191

5.3 PERSPECTIVES. 191

6 RÉFÉRENCES BIBLIOGRAPHIQUES 194

7 ANNEXES 208

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