Multi-scale Quantitative Diagenesis and Impacts on Heterogeneity of Carbonate Reservoir Rocks, 1st ed. 2017 Advances in Oil and Gas Exploration & Production Series

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TABLE OF CONTENTS

 General Summary of Scientific/Academic Activities xvii

 Chapter 1: Introduction

1.1. Diagenetic realms 1

1.2. Porosity and diagenesis 4

1.3. Quantitative diagenesis 7

1.4. Numerical modelling of diagenesis 9

1.5. Objectives and way forward 13

 Chapter 2: Characterization of diagenesis

2.1. State of the art (Characterization of diagenesis) 15

2.1.1. Fieldwork 16

Pre-microscopic observations 18

Microscopic observations 19

2.1.3. Geochemistry 20

Major and trace element analyses 20

Stable oxygen and carbon isotopic analyses 21

Strontium isotope analyses 21

2.1.4. Mineralogy 22

IFPEN protocol for XRD 22

Electron microprobe 23

2.1.5. Fluid inclusions 24

Microthermometry 24

Crush-leach analyses 24

2.2. Future perspectives 27

2.2.1. Clumped oxygen isotopic analyses 27

2.2.2. Mg isotopic analyses 28

2.2.3. 3D porosity 30

Micro-CT setup and 3D-image reconstruction 31

Building an equivalent pore network from the actual pore space 31

Numerical simulation of mercury intrusion and permeability 34

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2.3. Discussion and personal contribution 35

2.3.1. General discussion 35

2.3.2. Personal contribution 37

Dolomitization 38

Sandstone diagenesis 39

Source rocks 39

2.4. Advancement in characterization of diagenesis 41

2.5. Samples of published articles in peer-reviewed journals 43

Chapter 3: Quantitative diagenesis

3.1. State of the art (Quantitative diagenesis) 99

3.1.1. Petrography – Plug/Sample scale 99

3.1.2. Petrography – Reservoir scale 102

3.1.3. Mineralogical analyses (X-Ray Diffraction) 106

3.1.4. Geochemical analyses – Thi

3.1.5. Geochemical analyses – Reservoir scale 110

3.1.6. Geochemical analyses – Basin scale 112

3.1.7. Fluid inclusion analyses – Petroleum systems 114

3.1.8. 3D Scanning (CT and micro-CT) and image analysis 117

3.2. Future perspectives 121

3.2.1. Remote sensing and photogrammetry 121

3.2.2. Integrated data analysis tools 122

3.2.3. Pore space models 123

3.3. Discussion and personal contribution 125

3.3.1. General discussion 125

3.3.2. Personal contribution 128

Fluid inclusion analysis 129

Integrated petrographic and petrophysical data analyses 129

Micro-CT and image analyses 129

3.4. Advancement in quantitative diagenesis 131

3.5. Samples of published articles in peer-reviewed journals 133

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 Chapter 4: Numerical modelling of diagenesis

4.1. State of the art (Numerical modelling

4.1.1. Geometry-based modelling 181

Karst networks modelling 181

Fracture-related hydrothermal dolomite mod

4.1.2. Geostatistical modelling 188

Methodology: Geostatistical parameterization steps 188

Methodology: Geostatistical simulation methods 191

Case study: Geostatistical modelling of the Upper Jurassic Arab D reservoir heterogeneity, Offshore Abu Dhabi, United Arab Emirates (Morad, 2012) 197

Alternative workflow for geostatistical modeling of the Arab D reservoir heterogeneity 215

4.1.3. Geochemical modelling 220

0D geochemical modelling: Dissolution/Precipitation rates 220

2D geochemical reactive transport modelling: Reflux dolomitization 223

3D geochemical reactive transport modelling: Compactional dolomitization 228

4.2.1. Geometry-based modelling 233

4.2.2. Geostatistical modelling 233

4.2.3. Geochemical modelling 234

4.2.4. Towards integraded geomodels 235

4.3. Discussion and personal contribution 237

4.3.1. General discussion 237

4.3.2. Personal contribution 241

Geometry-based modelling 241

Geostatistical modelling 242

Geochemical modelling 242

4.4. Advancement in numerical modelling of diagenesis 245

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 Chapter 5: Petroleum systems and basin evolution

5.1. The Levant Basin 283

5.2.1. Forward stratigraphic modelling 290

Methodology (DionisosFlowTM) 291

Levant Basin forward stratigraphic model 293

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5.2.2. Basin modelling 299

Methodology (TemisFlowTM) 300

Lithofacies transfer from DionisosFlowTM to TemisFlowTM 301

Levant Basin model 309

5.3. Future perspectives 317

5.3.1. Towards integrated stratigraphic basin models 317

5.3.2. Towards integrated basin/reservoir models 319

5.4. Discussion and personal contribution 321

5.4.1. General discussion 321

5.4.2. Personal contribution 324

Stratigraphic modelling 324

Petroleum systems modelling 324

Structural modelling 325

5.5. Advancement in numerical integrated modelling 327

5.6. Samples of published articles in peer-reviewed journals 329

6.1. Characterization techniques and workflows 374

6.2. Quantitative techniques and workflows 375

6.3. Modelling techniques and workflows 376

6.4. Integrated modelling workflows 377

6.5. Way forward and research strategy 378

 References 381

 Extended curriculum vitae 399

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LIST OF FIGURES

Figure i. From conceptual to numerical modelling of diagenesis, quantifying diagenetic phases remains essential…………………………………………………………………………………………….... xvi

Chapt

Figure 1- 1. Schematic representation of major diagenetic realms, related processes and resulting products in a carbonate platform.…………………………………………………………………...…………….... 1

Figure 1- 2. Field photograph showing the Lower Cretaceous microbialithes of the Qishn Formation in Wadi Baw (Oman) during a field visit with Petrobras (in 2007)…………………………………………... 3

Figure 1- 3. Diagenesis occurs in depositional and erosional environments with distinct spatiotemporal zones: Eogenetic, Mesogenetic and Telogenetic……………………………………………………………. 4

Figure 1- 4. Schematic illustration of porosity evolution during diagenesis: progressive dissolution (from mould to vug) and porosity reduction by cementation……………………………………………………… 5

Figure 1- 5. Porosity 3D network building based on micro-CT and image analyses (from De Boever et al., 2012)…………………………………………………………………………………………………. 6

Figure 1- 6. Integrated techniques for constraining flow properties (porosity and permeability) dur

Figure 1- 7. Photograph showing the extent of hydrothermal dolomites (dark brown) in platform carbonates (Ranero, northern Spain)…………………………………………………………………………….. 7

Figure 1- 8. 3D cube of a typical Jurassic Arab C dolostone sample (Middle East), which have been scanned with micro-CT at resolution of 1.5 μm………………………………………………………………. 8

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Figure 1- 10. Geometry-based modelling of the fracture related Ranero hydrothermal dolomites (northern Spain)………………………………………………………………………………………………… 10

Figure 1- 11. Results of geostatistical stochastic joint simulations of sedimentary facies and diagnetic imprints of the three stratigraphic units in the Madison Formation, Wyoming – USA………………………. 11

Figure 1- 12. Results of reactive tran

Chapter 2: Characterization of diagenesis

Figure 2- 1. Map showing dolomite occurrence and fracture (fault) lineaments in Cretaceous platform carbonate rocks exposed in Ranero (NE Spain)………………………………………………………………… 16

Figure 2- 2. Out-crop scale petrographic observations on the world class fault-associated dolomites in the Ranero, Pozalagua quarry/auditorium (NE Spain)…………………………………………………... 17

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Figure 2- 3. Stained polished, etched slab of dolomite from the Ghalilah Formation (Upper Triassic) in Ras Al Khaimah (UAE)……………………………………………………………………………………… 18

Figure 2- 4. SEM backscattered electron image (left) and cluster analysis of electron microprobe map (right), as well as mean structural formula for two different dolomites………………………………………... 2

Figure 2- 6. Examples of conceptual dolomitization models and their schematic geometries and extent… 26

Figure 2- 7. Interpolated (solid) line of Δ47 values (in ‰) and corresponding temperatures (in K) for inorganic and organic carbonates (from Eiler, 2007)…………………………………………………………... 28

Figure 2- 8. Theoretically predicted Mg isotope fractionation factors (from Li et al., 2012 and references therein)……………………………………………………………………………………………….. 29

Figure 2- 9. Extracted macro-pore network for the Estaillades carbonate rock standard. ………………… 30

Figure 2- 10. (A) 3D grey scale view of micro-CT scan (2000x1000x1000 pxls) of a typical Jurassic Arab C dolostone (Middle East). (B) Grey level histogram (De Boever et al., 2012)……………………….. 32

Figure 2- 11. Equivalent network building of the actual pore

Figure 2- 12. Simulated and measured mercury injection capillary pressure curve of the actual pore structure of a typical Jurassic Arab C dolostone (Middle East)………………………………………………….. 34

Figure 2- 13. Burial model for a well intercepting Khuff equivalent reservoirs (Kangan Formation) in the Salman field, offshore Iran (Peyravi et al., 2014 )………………………………….……………….. 36

Chapter 3: Quantitative

Figure 3- 1. Scanning electron microscope (SEM) photomicrographs coupled with nuclear magnetic resonance (NMR) T2 distribution graphs of two typical carbonate rocks ……………………………………… 100

Figure 3- 2. Correlation cross-section (constructed by EasyTraceTM software based on petrographic analyses of thin sections) ………………………………………..……………………………………………….. 103

Figure 3- 3. Statistical analyses of well data based on 10000 thin sections (and samples) from 13 wells (Arab D, Midd

Figure 3- 4. Proportional maps showing: (i) the dolomite distribution (A: Wackestone-Packstone; B: Packstone-Grainstone; C: Mudstone-Wackestone); and (ii) the relative abundance of the syntaxial calcite overgrowth cement (D: wackestone-Packstone; E: Packstone-Grainstone; F: Mudstone-Wackestone) in the Arab D member of an investigated oilfield offshore Abu Dhabi (UAE)…………………………………….. 105

Figure 3- 5. XRD and Rietveld diagram showing the quantitative assessments of calcite, dolomite and anhydrite in a Triassic carbonate rock from the French Jura…………………………………………………... 106

Figure 3- 6. Cross-plot diagram of dolomite stoichiometry (%Ca in dolomite) versus dolomite cell parameter (c in Å) featuring data from various sources…………………………………………………………… 107

Figure 3- 7. Unit cell dimensions of Upper Muschelkalk and Lettenkohle dolomites…………………….. 108

Figure 3- 8. Spectral analysis

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Figure 3- 9. Detailed geological map of the Marjaba dolostone front with discordant geometry and its surrounding limestone host-rock (central Lebanon; Nader et al., 2007)……………………………. 110

Figure 3- 10. Fe and Mn concentration contour maps (A) and cross-plot (B) for the Marjaba HDT front (central Lebanon; concentrations in ppm)……………………………………………………………………. 111

Figure 3- 11. Schematic illustration representing the typical fracture-filling cement stratigraphy………… 113

Figure 3- 12. Calculated oxygen stable isotopic composition ranges of the ‘parent’ diagenetic fluids (expressed in δ18O VSMOW) for dolomite and calcite cement phases………………………………………..… 113

Figure 3- 13. Workflow for dating unaltered (preserved, A and D) and re-equilibrated (B and E) fluid water (aqueous) and petroleum inclusions…………………………………………………….…………… 116

Figure 3- 14. Examples of training i

Figure 3- 15. Calculation of porosity% for increasing volumes to investigate the representative elementary volume of the studied sample…………………………………………………………………….….. 119

Figure 3- 16. 2D-grey scale view of CT scan of a typical dolomitized grainstone………………………… 119

Figure

Figure 3- 18. Hyperspctral image analysis and interpretation of the main face of the Pozalagua Quarry (Ranero, NE Spain; from Kurz et al., 2012)…………………………………………..……………………….. 122

Figure 3- 19. Rock-Eval pyrolysis results for identifying and quantifying carbonate species)…………….. 127

Chapter 4: Numerical modelling of diagenesis

Figure 4- 2. Improved workflow for ODSIM of karstic networks…………………………………………. 183

Figure 4- 3. Simulated envelope of a karstic network skeleton obtained by taking into account the bedding plane (H1) – a stratigraphic feature, a fault (F1) – a structural feature, and an ‘attraction level’ (water-table) coinciding with the lowest conduits………………………………………………………...……….. 184

Figure 4- 4. Top views of the Ranero model (6000 x 2000 m) showing the two study areas (outlined in black) and the distribution of dolomites (brown) within the original sedimentary facies………………..… 185

Figure 4- 5. Based on field data and conceptual models, the Ranero fault-related dolomites can be further constrained by applying a distance decreasing control for the dolomite occurrence along fau

Figure 4- 6.

Figure 4- 7. The principle of computing a vertical proportion curve (VPC)………………………….……. 189

Figure 4- 8. Schematic representation of the computation of VPCs and VPMs……………………….…… 189

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Figure 4- 9. An example of a variogram showing its characteristic parameters…………………………… 190

Figure 4- 10. Influence of variogram model type (A: Exponential; B: Spherical; and C: Gaussian) on the resulting distribution of modelled properties………………………………………………..………. 191

Figure 4- 11. (A) The principles of the Sequential Indicator Simulation (SIS). (B) The way categorical variables are transformed into indicator functions……………………………………………………………...192

Figure 4- 12. The principle of truncated Gaussian approach……………………….…

Figure 4- 13. The plurigaussian method and related parameters……………………………………...……. 194

Figure 4- 14. The multiple-point geostatistics applied on channels…………….………………………….. 195

Figure 4- 15. Schematic depositional model of the Arab D and C members……………………….……… 197

Figure 4- 16. Three well-logs from southeast outer ramp to the northeast inner ramp across the investigated field, showing the rock texture dist

Figure 4- 17. Simplified map showing the investigated field (~20 x25 km) at the PS3 interval, the extent of the depositional facies, as well as the locations of wells………………………………………………… 199

Figure 4- 18. Photomicrographs (PPL) displaying characteristic lagoon microfacies in PS3……………… 200

Figure 4- 19. Photomicrographs (PPL) displaying examples of shoal microfacies in PS3………………… 200

Figure 4- 21. Photomicrographs (PPL) displaying characteristic outer ramp microfacies in PS3…………. 201

Figure 4- 22. Cross-plots of bulk porosity (%) versus log-permeability analysed based on the abundance of SCOC and dolomite% within the PS3…………………………….…………………………………. 203

Figure 4- 23. Geostatistical modeling workflow for the distributions of rock textures (in three classes: grainy, packstone, muddy), the SCOC (in four classes: absent, rare, common, abundant), dolomite (%) and porosity (%) in PS3………………………………………………….………………………………. 204

Figure 4- 24. (Left) Depositional facies map showing the location of the wells (hard data) across the investigated field. (Right) Computed vertical proportion curves (VPCs) representing the vertical rock textures distributions in each of the ten wells…………………………...……………………………………. 205

Figure 4- 25. Property map showing the extent of the depositional

Figure 4- 26. Co

Figure 4- 27. Top view of the modelled rock textures distribution in PS3…………………………………. 207

Figure 4- 28. (Left) Depositional facies map showing the location of the wells (hard data) across the investigated field. (Right) Reported well-logs data representing the vertical SCOC abundance distributions in each of the ten wells………………………………………………………………………………………….. 208

Figure 4- 29. Property map for constraining the distribution of SCOC in PS3……………………….……. 209

Figure 4- 30. Constrained proportion matrix (VPM) for SCOC in PS3…………………...……………….. 210

Figure 4- 31. Top view of the modelled SCOC distribution in PS3……………………………...………… 211

Figure 4- 32. Top view of the modelled dolomite distribution in PS3………………………….………….. 212

Figure 4- 33. View of the porosity attribution in PS3, based on the modelled distributions of rock textures, SCOC and dolomite as well as the diagenetic drivers rules…………………….…………………… 213

Figure 4- 34. View of the permeability attribution in PS3, based on the modelled distributions of rock textures, SCOC and dolomite as well as the diagenetic drivers rules…………………………………………. 214

Figure 4- 35. Geostatistical modelling workflow for the distributions of facies (rock textures in three classes: grainy, packstone, muddy) by means of plurigaussian method……………………………

Figure 4- 36. Results of the two Gaussian simulations

Figure 4- 37. Distributions of rock textures (facies; A), porosity in % (B), SCOC (C) and permeability in mD (D) based on geostatistical modelling involving plurigaussian, FFT-MA, collocated cokriging methods for the PS3 interval (Upper Jurassic Arab D Member)…………

Figure 4- 38. General characteristics of reflux dolomite model………………………………………...….. 223

Figure 4- 39. Conceptual model of reflux dolomitization, including both processes of replacement of calcite and precipitation of dolomite cement (overdolomitization)……………………………………………… 225

Figure 4- 40. Simulation results of reflux dolomitization 2D geochemical RTM with the original brines at 50°C and in three time steps (0.1, 0.2 and 0.3 m.y. after the start of fluid injection)…………………...…. 226

Figure 4- 41. A typical example of sensitivity analyses demonstrating the influence of the reactive surface areas (102 and 104 cm2/g) on the modelled dolomite and anhydrite precipitations as well as porosity; from Jones and Xiao (2005)………………………………………………………………..…………………….. 227

Figure 4- 42. Simplified map and cross-section showing the paleogeographic configuration at the Jurassic times of the Po Plain and the southern Alps (from Consonni et al., 2010)………………………………… 228

Figure 4- 44. Results of the 3D geochemical reactive transport model (RTM; with TOUGHREACT code) covering the Malossa Paleohigh…………………………………………………...………………… 230

Figure 4- 45. Results of the 3D geochemical reactive transport model of the Malossa Paleohigh highlighting the impact of two different configurations of faults/fractures………………………...…………………. 231

Figure 4- 46. Towards integrated basin/reservoir geomodels……………………………...……………….. 235

Figure 4- 47. Results of geochemical RTM simulations achieved by ArXim-CooresTM representing the formation of hydrothermal dolomite fronts (dolomite, anhydrite and porosity%)………………….. 240

Chapter 5: Petroleum systems and basin evolution

Figure 5- 1. Schematic representation of major diagenetic processes within basin-scale and/or reservoir-scale evol

Figure 5- 2. Schematic map showing the Levant Basin and the major oil/gas fields in the East-Mediterranean region and northern Arabia (from Nader, 2014a)……………………………………………………. 282

Figure 5- 3. Petroleum systems model for onshore and offshore Lebanon showing potential source rocks, migration pathways, plays and seals (slightly modified from Nader, 2014b)……………….………. 284

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Figure 5- 4. Chronostratigraphic chart showing observed

Figure 5- 5. Un-interpreted and interpreted south-north 2D seismic profile offshore Lebanon (courtesy of PGS), showing the structure of the Levant margin…………………………………………………………. 286

Figure 5- 6. An example of west-east oriented 2D seismic profile across the Levant Basin offshore northern Lebanon……………………………………………………………………………………………… 287

Figure 5- 8. Field photograph of the organic-rich Campanian lime-mudstone facies exposed in the Chekka quarries (Cimenterie Nationale sarl.) in northern coastal Lebanon………………………………..… 289

Figure 5- 9. Conceptual model proposed for the eastern margin of the northern Levant Basin………...…. 290

Figure 5- 10. Input parameters and sediment accommodation calculation with DionisosFlowTM……...….. 292

Figure 5- 11. Constraining data for the forward stratigraphic model based on regional studies, seismic interpretation, fieldwork, and well correlations………………………………………………….….. 293

Figure 5- 12. Coverage

Figure 5- 13. Schematic block-diagrams illustrating the Miocene depositional environments for the Levant Basin and its eastern margin………………………………………………………...……………….. 295

Figure 5- 14. Results of carbonate production modelling at the margin and in the basin based on the best-fit model (from Hawie et al., in press)……………………………………..…………………………… 296

Figure 5- 15. Results of the Levant Basin best-fit stratigraphic model (from Hawie et al., in press)…….... 297

Figure 5- 16. Best fit simulation for the Levant Basin stratigraphic filling between 16 and 6Ma…………. 298

Figure 5- 17. Northward view of the Levant basin model with simplified lithological facies…………...… 299

Figure 5- 18. TemisFlowTM Map Editor depth map to the top of the Triassic rock series………………..... 300

Figure 5- 19. Illustration of

Figure 5- 20. Bathymetry map (in meters) of present day seabed and onshore surface (Top Pliocene – Quaternary)………………………………………………………..…………………………………. 302

Figure 5- 21. Thermal calibration in based on well data and surface exposed Cretaceous rocks……….…. 304

Figure 5- 22. Basal heat flow variation through time for the six pseudo wells within the Levant Basin…...

Figure 5- 23. Transformation ratio map of the Permian Type III source roc

Figure 5- 24. Transformation ratio history of the Permian source rocks at the six pseudo wells…….…….. 309

Figure 5- 25. Transformation ratio map of the Kimmeridgian source rocks across the Levant Basin and margin (Bou Daher et al., submitted)…………………………………………………………….………….. 310

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Figure 5- 27. Transformation ratio map of the Neocomian source rocks across the Levant Basin and margin (Bou Daher et al., submitted)………………………………………………………………………... 311

Figure 5- 28. Transformation ratio history of the Neocomian source rocks at the four pseudo wells….….. 311

Figure 5- 29. Transformation ratio maps of two Campanian source rocks with distinct activation energies across the Levant Basin………………………………………………………………………..……………. 312

Figure 5- 30. Transformation ratio history curves of the two distinct Campanian source rocks across the Levant Basin…………………………………………………………………………………………...…….. 312

Figure 5- 31. Palaeogeographic map of the Levant region showing depositional environments in the Late Cretaceous times (Bou Daher et al., submitted)…………………………..…………………………. 313

Figure 5- 32. EW section across the constructed model showing the calculated vitrinite reflect

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Figure 5- 34. Plot of activation Energy (E), preexponential factor (A), and error function, for one of the analyzed samples (12/134), showing the different possible E and A couples for a minimum error function… 318

Figure 5- 35. From left to right these are the P10, P50, and P90 transformation ratio maps using one of the analysed soure rock samples…………………………………………………………………...……. 318

Chapter 6: Conclusions and general perspectives

Figure 6- 1. Proposed future operational workflow for tackling diagenesis: (A) Conceptual studies of diagenesis – for example hydrothermal or high temperature dolomitization (HTD; Nader et al., 2004, 2007); (B) Quantitative diagenesis methods – e.g. micro-computed t

Figure 6- 2. My research strategy on the general theme of “multi-scale integrated numerical modeling of diagenesis” for the coming three years (until 2018). Two parallel clusters of programmes are indicated (Diagenesis and Geological models). Principal cross-cluster themes are also indicated (upscaling, REV; scales and methods; case st

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LIST OF TABLES

Chapter 2: Characterization of diagenesis

Table 2- 1. Total list of material used throughout a typical diagenetic study (Nader, 2003)………………. 17

Table 3- 1. Various lithological and textural categories for describing carbonate microfacies ……………. 101

Table 3- 2. Categories for describing cement in microfacies (thin sections)…………………………….… 101

Table 3- 3. Categories for describing reservoir properties in microfacies (thin sections)………………….. 102

Chapter 4: Numerical modelling of diagenesis

Table 4- 1. The quantitative impact of diagenesis on reservoir quality for the various depositional facies and rock textures in PS3……………………………………………………………………..…………… 202

Table 4- 2. The simulation method and variogram values for the rock textures distribution of PS3………. 207

Table 4- 3. The simulation method and variogram values for the SCOC distribution of PS3…………..….. 210

Table 4- 4. Variogram model for the

Table 4- 5. Parameters for the collocated cokriging simulations of the SCOC distribution in packstone rock-textures across the study area, and constraints for the variogram model…………….……………… 217

Table 4- 6. Para

Table 4- 7. Applied conditional formulas for calculating permeability values based on simulated porosity per rock texture (facies) taking into account the SCOC distribution…………..……………………… 218

Table 4- 8. Geochemical compositions of the fluids (associated to dolomite dissolution and anhydrite precipitation) used in reaction path calculations……………………………………….……………. 221

Table 4- 9. Quantitative diagenesis of three samples from the Arab Formation (Abu Dhabi – UAE) by means of micro-CT image analyses and XRD (from De Boever et al., 2012)…………..…………………….. 222

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Chapter 5: Petroleum systems and basin evolution

Table 5- 1. Results of bulk rock analysis with Rock-Eval6 for selected source rock samples………….….. 306

Table 5- 2. Pure organic matter Rock-Eval6 results for selected source rocks samples after acid treatment and DCM extraction (from Bou Daher et al., submitted)……………………………………..………….. 306

Table 5- 3. XRD results pre- and post-acid treatment of source rocks……………………………….……. 307

Table 5- 4. Mean activation energies and frequency factors for se

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DEFINITIONS

AvizoTM 3D analysis software application for exploring and understanding materials structures and properties, in a wide range of materials science research areas (FEI).

CobraFlowTM Software for performing geologically meaningful simulations using geostatistical algorithms (IFPEN and Centre of Geostatistics of the Paris School of Mines).

CooresTM (CO2 Reservoir Environmental Simulator), a research code designed to study CO2 storage processes from the well to the basin scale (IFPEN). It simulates multi-component three-phase and 3-D fluid flow in heterogeneous porous media. To take into account mineralogy changes, the transport model is coupled with ArXim.

DionisosFlowTM (Diffusion Oriented Normal and Inverse Simulation Of Sedimentation), a deterministic 3D multi-lithology stratigraphic modelling software that simulates depositional processes in a sequence of steps moving forward in time (IFPEN).

EasyTraceTM A multi-disciplinary 1D data processing and editing tool, featuring advanced spreadsheets and a wide range of functionalities for geologists and geophysicists (IFPEN).

EOR Enhanced Oil Recovery.

FracaTM Software capable of characterizing, modelling and calibrating faults and fractures. It bu

GOCAD (Geologic

InterWellTM Software capable to analyse post, pre stack and 4D seismic data, to compute multi cubes seismic wavelet calibrated at wells and to build a priori seismic impedance cubes honouring wells and stratigraphic data (IFPEN).

JMicroVision A freeware designed to describe, measure, quantify an

MatlabTM A high level programming language and interactive environment capable of advanced numeric computation, data analysis and visualization, programming and algorithm development and application (Mathworks).

PHREEQ-C. A computer program designed to perform a wide variety of aqueous geochemical calculations. It implements several types of aqueous models and is capable of undertaking speciation, saturation-index, and transport calculations (USGS).

TemisFlowTM Basin modelling software package for assessing regionally controlled petroleum systems and basin evolutions. It calculates the generation, migration and accumulation of fluids (IFPEN).

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Dr. habil. Fadi Henri Nader is an Engineer Sedimentologist at the IFP Energies nouvelles (formerly: Institut Français du Pétrole, IFP). He is working on diagenesis (fluid-rock interactions) and its impacts on reservoir properties (porosity/permeability) at the plug-, reservoir- and basin-scales. he has also launched several new research projects related to reflection seismic interpretations and modelling of frontier basins.

Reinforces basic principles with well documented case studies and scientific arguments

Maximizes reader insights into quantitative aspects of diagenesis and reservoir rocks characterization

Provides new, creative workflows to undertake reservoir characterization

Includes supplementary material: sn.pub/extras