Publications

Beicip-Franlab will present the following talk at 84th EAGE Annual 2023.

Geomodelling and iterative dynamic simulations for the determination of flow units in fluvial settings

By A. Fournillon¹, S. Charonnat¹, A. Bonnel¹, G. Suzanne¹, B.W. Horn², A. Ahmed², A. Tiwari², R. Sharda², A. Kumar², G. Sharma², J. Das²
1 Beicip-Franlab
2 Cairn

https://doi.org/10.3997/2214-4609.202310782

Abstract :

Fluvial depositional environments represent a key challenge in reservoir modeling Their highly complex reservoir architecture is combined with high sedimentary heterogeneity. It results in a complex fluid flow with preferential pathways, small dynamic compartments, and thief layers, leading to a degraded recovery. The aim of this study is to, first, define flow units representing the main connections between wells. This is based on a close integration of static data, like cores, well-logs patterns and geophysics, and dynamic data, like water breakthrough analysis, injectivity logs or MDT. Then, it is to model these flow units in a 3D geocellular grid and performed iterative history matching. This iterative matching aims at finding the best solution of connectivity between wells based on simulation of water arrival, water cut and pressure. Evolution of the quality of the match compared to flow unit edition shows that iterations are needed to achieve correct history match due to this high sedimentary complexity. It shows also that the number of edition is not directly linked to the quality of the history match. The latter is rather affected by threshold effect compared to the number of editions.

Beicip-Franlab will present the following talk at 84th EAGE Annual 2023.

Applications of Basin Modelling for the Energy Transition Subsurface Challenges

By G. Pérez-Drago, M. Dubille, S. Arsenikos, G. Maury, M. Callies, E. Marfisi, A. Thebault
Beicip-Franlab

https://doi.org/10.3997/2214-4609.2023101239

Abstract :

Geosciences have a fundamental role to play searching for new renewable and sustainable sources of energy in the underground and helping to reduce carbon dioxide emissions to the atmosphere. The oil industry has long been a powerful engine of technical innovation. The numerical tools developed and applied over decades will now help to reduce certain environmental problems resulting from human activities. Among these technologies, basin modelling can help derisking and better understanding the subsurface processes related to the Energy Transition, being a catalyst in the decision-making process to maximize investment profits and avoid risk-related costs.

The physics embedded in the current sophisticated basin models constitute a solid base for further geological investigations, since the same theory is flexible and applicable to all geological processes independent of their final purpose of investigation.

This paper presents three different applications where basin modelling plays an important role to address some of today’s challenges in Energy Transition: 1) heat energy resource assessment through deep geothermal system modelling, 2) saline aquifer carbon storage potential screening, and 3) natural hydrogen play analysis. We will see how large-scale and long-term geological modelling helps in the characterization of prospective areas, presenting present-day technologies, and discussing possibles future evolutions.

Beicip-Franlab will present the following talk at 84th EAGE Annual 2023.

Leveraging high-resolution basin and reservoir modeling for CCUS and geothermal potential screening, Middle Magdalena Valley, Colombia

By E. Lopez¹, H. Cubillos¹, S. Granet², A. Thebault², F. Medellin³, G. Pérez-Drago², S. Arsenikos², S. Bou Daher²
1 Ecopetrol
2 Beicip-Franlab
3 Beicip Inc

https://doi.org/10.3997/2214-4609.2023101240

Abstract :

Carbon capture storage (CCS) and geothermal systems in sedimentary basins are often limited by seismic and well data availability, historically acquired to target hydrocarbon resources. Nevertheless, those targets and the CCS and/or geothermal systems may or may not overlap and could appear to be around raw data blind spots, presenting the challenge of requiring time and cost-effective technologies/workflows that could fill the gap and provide valuable insights during the pre-feasibility and global screening process.

The Middle Magdalena Valley Basin is a mature oil and gas province with most of the exploitation being produced from conventional fields in the Cenozoic section, predominantly from fluvial/alluvial environments. Furthermore, tight, and unconventional resources have been studied in the Mesozoic, predominantly from marine and shallow marine environments with less data.

Calibrated heat and fluid flow coupled simulations, provided a 3D cube of temperature, pressure, petrophysical and constitutive features for reservoirs and cap rocks; these parameters, in conjunction with CO2 thermodynamics and solubility, have been built into a java script that can quantify and report the theoretical total CO2 mass per sequence, expected CO2 column and its associated injectivity, operational and environmental risk. Moreover, theoretical extractable electric potential is calculated in the 3D volume.

A fruitful collaboration between Beicip-Franlab and IFPEN employees resulted in a book chapter in the Springer Advances in Science, Technology, & Innovation book series (ASTI). This contribution discusses the significance of source rocks forward modelling and explains the approach and methodology used and embedded in DionisosFlow^®.

Source Rocks Forward Modelling: Significance and Approach

Samer Bou Daher¹, Benoit Chauveau², Erwan Leguerroue¹, Paul Jermannaud¹, Alcide Thebault¹, Maria-Fernanda Romero-Sarmiento²,  Emerson Marfisi¹

1 - Division of Global Solutions, Beicip-Franlab, Rueil-Malmaison, France
2 - IFP Energies Nouvelles, Directions Géoscience, Rueil-Malmaison, France

https://link.springer.com/chapter/10.1007/978-3-031-16396-8_4

Abstract

Organic matter rich rocks are the basis of any petroleum system. The nature and variability of organofacies in sedimentary rocks have been well documented for a large number of source rocks.
Significant effects of these organofacies heterogeneities on the source rocks hydrocarbon generation potential and kinetics have also been reported, therefore highlighting the importance of numerical source rocks prediction tools in petroleum systems analysis.
Efforts to numerically model organic matter deposition through earth’s history have been made with various degrees of success. However, none of these efforts have yet been integrated in hydrocarbon exploration workflows due to the time and resource needed to properly do so.
In this chapter, we present a new methodology to model marine organic matter. The advantage of this methodology is that it is coupled with an established forward stratigraphic modelling workflow, therefore requiring minor additional input and time to provide a quantification of source rocks distribution and properties.
The integration of this approach with traditional petroleum systems modelling solutions makes it a value adding tool in petroleum exploration efforts.

Beicip-Franlab will present the following talk at IMAGE 2022, Houston, Texas.

Reservoir characterization using multi-seed stochastic inversion

Vincent Thomas, Nicolas Desgoutte and Nathalie Lucet
Beicip-Franlab

https://library.seg.org/doi/epdfplus/10.1190/image2022-3745242.1

Abstract

In this paper, we compare inversion results obtained with deterministic and stochastic approaches.
After short description of the inversion techniques, results are presented on real data case, in a shale/sand clastic environment where sand layer thickness is way below seismic resolution.
Next, two seismic reservoir characterization tools, namely discriminant analysis and multi-variate regression, have been applied on the two sets of inversion results and are compared.
Finally, 4 runs of stochastic inversion, using 4 different seeds enable to dispose of a large set of simulated impedance cubes, leading to a more reliable analysis of shale volume, and to the associated variance cube that gives a good insight on uncertainty attached to reservoir parameter estimates.

Beicip-Franlab will present the following talk at IAP 2019, Algeria.

Methodology for Multi-Component Inversion

N. de Freslon, N. Lucet, N. Desgoutte
Beicip-Franlab

Abstract

Seismic inversion, carried out on PP wavefield data, is widely used to assess elastic parameters related to reservoir properties. When available, PS seismic data can help significantly enhancing the image of the reservoir. PP-PS joint inversion allows the use of two independent wavefields to provide an enhanced S-impedance along with an optimized density, in addition to the P-impedance already obtained with high quality using PP data only. The combined use of these three parameters increases our ability to predict lithology and fluid distributions from seismic data.
In this case study, the presence of a gas cloud leads to strong amplitude dimming, increasing drastically the uncertainties about the reservoir properties. Using joint inversion allows to overcome this imaging issue by using PS wavefield - not affected by the presence of gas - in addition to PP wavefield. PP-PS joint inversion allows obtaining:
- Optimized P and S-impedance and density.
- Better reservoir architecture in the area affected by the gas presence.

Density section resulting from PP-PS inversion

Beicip-Franlab will present the following paper in 2021, First Break, volume 39.

Integration of VSP in the process of surface seismic data inversion

N. de Freslon*, L. Cuilhe*, S. Yareshchenko**, Y. Solodkyi**, I. Gafych**, C. Rudling***, N. Lucet*, N. Desgoutte* and V. Machault*
*Beicip-Franlab, **DTEK, ***RPS

https://www.earthdoc.org/content/journals/10.3997/1365-2397.fb2021041

Abstract

The measurements of vertical seismic profiles (VSP) used in the petroleum industry are often limited to direct arrivals to establish time-depth laws. Many other measurements such as PP and PS corridor stacks, offset vertical seismic profiles (OVSP) and walkaway can help to predict P and S wave impedances estimated by inversion of surface seismic data.
This article shows the use of all available VSP records to constrain the inversion of surface seismic data and predict matrix properties of Carboniferous and Devonian intervals in the Machukhske gas field in the Ukrainian Dnieper-Donetsk basin.
The use of PS corridor stack, in addition to PP corridor stack, allows a better optimization of the S impedance at the well. Moreover, corridor stacks allow a better estimate of the P and S impedance below the well TD than surface seismic data alone, and therefore an enhanced characterization of the Devonian sands, which has been drilled by only a few wells. OVSPs help build a more reliable a priori model by confirming or discarding the faults identified on the 3D seismic.
Results of reservoir characterization show a clear impact of the VSP integration on lithology prediction from surface seismic data.

Optimized P-impedance sections resulting from WVSP and surface seismic data (left) and P-impedance traces comparison (right): well-log P-impedance in black, optimized P-impedance from WVSP inversion in blue and from surface data inversion in red

Beicip-Franlab will present the following talk at EAGE 2021.

Use of classification technique to characterize porous carbonate reservoir in Machukhy field, onshore Ukraine, 2021

N. de Freslon*, L. Cuilhe*, S. Yareshchenko**, C. Rudling***, N. Lucet*, N. Desgoutte*, V. Machault*, Y. Solodkyi** and I. Gafych**
*Beicip-Franlab, **DTEK, ***RPS

https://www.earthdoc.org/content/papers/10.3997/2214-4609.202112537

Abstract

Seismic reservoir characterization, following a seismic inversion, plays a key role to capture the vertical and lateral variations of matrix properties for advanced geosciences workflow. Geological constraint can be obtained by using a classification technique trained by well data samples such as discriminant analysis, which is a Bayesian supervised approach, to obtain probability of assignment into facies. Additional properties such as porosity can therefore be characterized depending on the predicted facies for more accuracy.
The present paper describes the work performed on the Machukhy field, focusing on the evaluation of Carboniferous carbonate reservoirs in the Ukrainian Dniepr-Donetsk Basin. The objective consists in performing model-based inversion (Aki and Richards, 1980) and reservoir characterization workflows in order to provide key elements to help predicting inter-well reservoir location, thickness and properties behaviour using inversion results and identifying possible drilling locations for development and exploration wells. The main targets are associated with the Tournaisian carbonate formation.
Reservoir characterization, following 3D PP surface seismic inversion, is performed to assess the reservoir potential of the area in term of facies and porosity distribution. A two-pass discriminant analysis is performed in order to first to isolate massive carbonate facies and predict the porous carbonate facies. Then, the porosity is predicted within the massive carbonate facies.

Discriminant analysis of porous carbonate facies after upscaling (a) Histogram of effective porosity distribution with a cut-off to define the porous carbonate facies (b) Inverted IP versus IS crossplot coloured by facies before assignment (c) Re-assignment histogram (d) Inverted IP versus IS crossplot coloured by the probability of good assignment into porous carbonate facies

Beicip-Franlab will present the following talk at EAGE 2021.

Forward Stratigraphic Modelling at reservoir scale, statistical comparison with common geostatistical methods and fractal behaviour

Arnaud FOURNILLON, Samer BOU DAHER, Emerson MARFISI, Nicolas HAWIE, Marie CALLIES
Division of Global Solutions, Beicip-Franlab, Rueil-Malmaison, France, 
arnaud.fournillon@beicip.com

Abstract

Capturing lithofacies heterogeneities and their associated petrophysical properties is a key challenge to provide reliable static models. The several geostatistical methods commonly used for this task apply a combination of hard and soft constraints provided from cores, well logs and seismic interpretation. A major challenge remains in bridging the resolution gap between these multi-disciplinary datasets and thus reproducing the geological complexity of depositional environments where few data is available.
In this communication, we propose an innovative approach that combines Forward Stratigraphic Modelling (FSM) with geostatistics in order to construct geomodels that accurately capture the reservoir heterogeneities while accounting for geological processes and uncertainties. Fractals and metrics of geobodies connectivity are used in order to quantify the benefits of such FSM method compared to Truncated Gaussian Simulation (TGS) and Sequential Indicator Simulation (SIS). It appears that forward stratigraphic modelling produces more realistic results compared to TGS and SIS. Both visual aspect and statistical parameters show that the obtained distribution of facies is more geologically sound. 
It enables both preserving the observed heterogeneity at wells and gaining in geobodies connectivity. 
This last parameter is a key advantage when passing from static to dynamic models.

Beicip-Franlab will present the following talk at EAGE 2021.

Geological Equiprobable Multi-Models for Resources Assessment. Carson, Bonnition and Salar Basin, NL, Canada

Presenter: Dr Erwan Le Guerroué (Beicip-Franlab) 
Author(s): E. Le Guerroué [1]*, P. Jermannaud [1], G. Perez-Drago [1], B. Lebreuilly [1], T. Pichot [1], P. Chenet [1], D. Norris [2], E. Gillis [2], R. Wright [2] 
Affiliation(s): [1] Beicip-Franlab; [2] Nalcor Energy

Introduction

The underexplored Carson, Bonnition and Salar basins appear prospective for oil and gas, after newly acquired regional 2D seismic data shows evidence of leads that have been tested using data-calibrated, equiprobable alternative petroleum system models. The objective of the petroleum system assessment was to provide petroleum resource estimates for the area through seismic structural and stratigraphic interpretation, and 2D/3D basin modelling for play risk analysis and volume estimates of hydrocarbon (HC) accumulation. Basin modeling was set up in order to account for alternative realistic (geologically possible) models. Such a multi-scenario approach was designed to account for some parameters that contained inherent uncertainty due to the limited data available in this frontier region.

Integrating Numerical Modelling Approaches in Conceptual Hydrocarbon Exploration

Beicip-Franlab will present the following talk at AAPG GTW Saudi Arabia 2019 

Nicolas Hawie¹

1 Beicip-Franlab, Rueil-Malmaison, France

Abstract

This communication discusses the return on experience of the latest innovation tackling Hydrocarbon Exploration in mixed sedimentary systems (i.e., carbonate, evaporites and siliciclastics) using integrated modelling approaches and sensitivity analysis.

Predicting the presence as well as the lateral and vertical extent and heterogeneities of Petroleum Systems elements remains a major challenge in the Oil and Gas industry as traditional conceptual and/or stochastic techniques appear to be insufficient in capturing vertical and lateral variability of facies and textures in complex reservoirs.

The use of Forward Stratigraphic models helps testing the proposed Conceptual Plays by achieving a more geologically sound and constrained 3D sequence stratigraphic framework that results in the generation of ecological, bathymetric and facies maps needed to better localize the development of reservoirs, seals as well as stratigraphic traps.

The workflow developed following various international projects (Arabian Plate, North and Central America, Europe) tackles the several limitations witnessed while using stochastic methodologies by (1) achieving a multi-disciplinary data integration, (2) accounting for the evolution of geological processes with time, (3) representing complex sedimentary geometries (algal mounds, reefs, aggradation, progradation, clinoforms), (4) assessing the sensitivity of the proposed geological model with regards to the evolution of environmental conditions and by (5) generating multiple plausible geological scenarios and facies probability/risk grids (6) Integrating the FSM results in a Basin Model to map the hydrocarbon expulsion, migration, charge and accumulation with regards to the tectonostratigraphic evolution of the system. The ultimate aim of this approach is to push the industry towards more geologically plausible and integrated numerical techniques to tackle the Play Fairway Assessment and de-risk petroleum systems elements. 

Exploring Siliciclastic Systems of Arabia Through Integrated Forward Stratigraphic Modeling and Multi-simulation Approaches

Beicip-Franlab will present the following talk at AAPG GTW Oman 2019 

 Nicolas Hawie¹

1 Beicip-Franlab, Rueil-Malmaison, France

Abstract

This work comes in the context of off-structure assessment of Paleozoic and Mesozoic siliciclastic systems of Arabia using innovative and integrated G&G approaches. Many challenges linked to the exploration of new hydrocarbon resources in such Mature Basins are driving innovative ideas towards the identification, the assessment and the de-risking of new subtle Plays. As important multi-scale and multi-disciplinary dataset (e.g., 2D, 3D seismic data, core and well log data and imagery…) have been acquired in the past decades along major structural features new frontiers are opening around major discovered sectors as well as in the offshore. This paper discusses the results of an innovative methodology developed to assess the detection of subtle stratigraphic trapping mechanisms using multi-disciplinary and multi-scale sedimentological, stratigraphic, petrophysical and geophysical techniques including seismic inversion and characterization as well as supported by regional process based deterministic DionisosFlow^® 4D forward stratigraphic models. The integration of CougarFlow^® automated multi-simulation approaches permits a better assessment of the impact of structural as well as environmental parameters on the sedimentary transport as well as deposition of fine versus coarse grained sediments laterally but also vertically. We also discuss the importance of stratigraphic scaling in the identification of sub-seismic stratigraphic traps and highlight the more consistent approaches to build sedimentary facies maps that are later integrated in petroleum systems models to simulate the impact of basinal evolution on hydrocarbon generation, migration and trapping. This workflow applied in mature sectors of the Arabian Plate sets new grounds for the generation of regional Play Fairway Maps, Common Risk Maps for the different Petroleum systems elements (reservoir, seal, trap and charge) as well as Composite Common Risk Maps. These tasks are aimed at assessing the overall risk associated to Plays and thus contribute to the identification of new exploration Lead Areas to be further de-risked in the near future

Coreflood Model Optimization Workflow for ASP Pilot Design Risk Analysis

Beicip-Franlab will present the following talk at MEOS Manama Bahrein March 2019

Olga Borozdina¹, Magnolia Mamaghani¹, Romain Barsalou¹, Martin Lantoine¹, Agnes Pain¹

1 Beicip-Franlab, Rueil-Malmaison, France.

Abstract

This work presents a new workflow to obtain a better-constrained reservoir-scale model for an Alkaline-Surfactant-Polymer (ASP) injection pilot design. It is explained how the impact of uncertain parameters related to ASP flooding can be quantified, using calibrated core-scale simulation based on experimental results, and how the influential parameters range for future reservoir-scale simulation can be determined. Computational costs of core-scale model are therefore much lower, and the final reservoir model is better constrained.
ASP flooding feasibility implies core scale studies, where chemical formulations are validated in the laboratory under field conditions. In the objective of the pilot designing, a numerical model is constructed and calibrated to history-match the core flood sequences: Remaining Oil Saturation (ROS), surfactant-polymer (SP) and polymer-alkaline (PA) injection and eventually the chase water slug. In order to quantify the impact of ASP chemical parameters on the history match, the Global Sensitivity Analysis (GSA) was performed using Response Surface Modeling (RSM). To obtain the acceptable range of influential parameters for future reservoir-scale simulation, the Bayesian optimization is used.
Applying this methodology on a real reservoir core, the laboratory measurements are accurately reproduced. Nevertheless, once the core-scale model was matched, the transition to reservoir-scale model must be done. Due to a large number of parameters and their associated uncertainties, this transition is not straight-forward. Thus, an additional step in our workflow is included. A new methodology is applied to firstly quantify the impact of uncertain parameters related to ASP flooding (adsorption of surfactant on the rock, critical micellar concentration, water mobility reduction by polymer etc.). To do so, the RSM is used and influential parameters are identified. In this study, the surfactant adsorption coefficients are the most influential parameters while others related to SPA have a poor impact on experiment results matching. Secondly, the acceptable range of influential parameters for future reservoir-scale simulation and feasibility study is obtained during Bayesian optimization. Thus, instead of using a wide (prior) range of uncertain parameters values, refined (posterior) distribution laws can be used for future reservoir model.
While the classical approach consists in matching experimental results to obtain calibrated values of certain properties (that are then entered in the reservoir model) and finally determine the influential parameters at the reservoir scale, here the choice was made to determine influential parameters and characterize their impacts at the core scale. This step helps to better constrain the reservoir model. Ongoing work is using the results of this workflow for pilot design and risk analysis.

Downward migration as a potential mechanism for HC accumulation in the Early Cretaceous Serdj and Allam plays of the Kaboudia Block, Gulf of Hammamet, offshore Tunisia.

Mouchot Nicolas¹, Doublet Stefan¹, Arab Mohamed², Hassaim Mohamed², Aissaoui Safia², Guizani Aymen², Bedjaoui Chakib², El Mahersi Chokri², Hmad Zakaria², Abderrahmane Rachedi², Karim Belabed³, Pierre-Yves Chenet¹

1 Beicip-Franlab - 232 avenue Napoléon Bonaparte, F-92500 Rueil-Malmaison, France
2 NUMHYD - Imm l'Union Centre .R du Lac de Mazuerie, Les Berges du Lac T-1053 Tunis, Tunisie
3 SIPEX

Abstract

The Kaboudia Offshore Permit is a prospective Mesozoic hydrocarbon province in the Gulf of Hammamet. The main petroleum system of the Kaboudia area comprises 2 proven plays in the Mid-Cretaceous time: the Aptian Serdj reservoir and the Albian Allam reservoir. These plays were proven positive with several oil discoveries in the area of interest.
The Mouelha organic-rich layer is a proven Late Albian regional source rock Tunisia. It is recognised onshore Tunisia and locally offshore when drilled by wells. Based on geochemical evidences, it is suggested that the regional Mouelha source-rock could feed these reservoirs. In this setting, the Mouelha SR is stratigraphically above the lower Allam and the upper Serdj reservoirs (Figure 1) leading HCs migration either by a “per descensum” migration process (Chi et al., 2010; Dubille et al., 2017) or by a fault-driven process.
Despite a fair knowledge of the elements of the petroleum system offshore Tunisia, no integrated study has been performed to evaluate the assumption on the petroleum system. In 2017, a complete 1D, 2D and 3D migration modelling study has been performed by Beicip-Franlab and Numhyd in order to synthetize information and to improve the knowledge on the mechanism that drives the HCs in the Allam-Serdj reservoirs.

Biogenic and Thermogenic Hydrocarbon Potential of the South Levant Basin and Eastern Nile Delta, Offshore

Beicip-Franlab will present the following talk at EAGE Egypt

Pérez-Drago G¹, Dubille M¹, Montadert L¹, di Biase D², Brivio L², Hosni M³, Zaky A³

1. Beicip-Franlab, Rueil-Malmaison, France.
2. Edison E&P, Milano, Italy.
3. Edison E&P Egypt Branch, New Cairo, Egypt.

Abstract

Edison E&P and Beicip-Franlab carried out a petroleum system analysis honoring recent 3D seismic interpretation and regional knowledge in a large area around the Edison’s operated license North Thekah Offshore (NTO), Egypt. The objective was to evaluate the hydrocarbon potential and the petroleum system efficiency of the area for derisking Plays and Prospects, through a 3D basin modeling approach accounting for biogenic and thermogenic hydrocarbons generation and charge. The methodology comprises a macroscopic modeling of microbial gas generation within a compositional kinetic scheme accounting for biogenic and thermogenic HC generation in function of thermal stress. Crustal heat-flow evolution with synchronous burial history and pore pressure regimes were simulated through geological time in order to identify favorable conditions for biogenic gas generation and preservation (heating rates ~7 to 18 °C/Ma). Simulated thermal and pressure variations during Messinian crisis had a significant impact on source rock expulsion timing and HC fluid migration and charge. HC expulsion and migration modeling evidences three (3) main Plays charged by local sources: 1) Lower/Late Oligocene biogenic to thermogenic source, charging Lower Miocene-Late Oligocene reservoirs and Cretaceous shallow water carbonates (locally liquid-rich thermogenic condensates), 2) Middle/Upper Miocene biogenic gas source, charging Middle/Upper Miocene reservoirs, 3) Pliocene biogenic gas source charging Plio-Pleistocene reservoirs.

Petroleum System Modeling in Complex Structural Settings: Application to the Bolivian Southern Andean Foothills.

Beicip-Franlab will present the following talk at AAPG ICE Buenos Aires, Argentina, August 2019

F. Schneider¹, A. Thebault¹, M. Callies¹, and R. Giraudo¹.

1 Beicip-Franlab, Rueil-Malmaison, France.

Abstract

Petroleum system modeling is recognized as a critical step in exploration workflows. However, fold and thrust belts are typical regions where classic basin modeling tools do not accurately manage the combination of lateral and vertical tectonic displacements. These complex areas require more accurate modeling approaches integrating active faulting, folding and fluid flow. The basin burial and geometry reconstruction, and fault connectivity should thus account for the horizontal deformation through time. Then, the basin simulator should use the produced kinematic scenario for the forward simulation of heat transfer, pressure, hydrocarbon generation, migration and accumulation considering the faults impact on fluid flow.

An application case from the Bolivian Southern Andean foothills illustrates the applicability of these technology and workflow. Preliminary structural reconstruction work detailing the main deformation phases of the area is used to guide the complete kinematic scenario. Forward basin simulation is then run and the model, calibrated to available well, outcrop, and field data, allows testing the impact of thrusting on maturation, migration pathways, and hydrocarbon charge.

The model is made of 15 stratigraphic units from Paleozoic to Present Day. Three source rock levels are included in the model, and main reservoirs are good sands deposited during the Paleozoic. The initial shortening is received between 12 and 10Ma from the Inter Andean and transmitted to the East until present day, resulting in a complex succession of thrusts, out of sequence thrusts and back-thrusts. The model shows good maturity levels with high transformation ratios for deepest source rocks. Hydrocarbon generation started during Permian-Triassic time and is boosted during Pliocene. It leads to a favorable timing for HC trapping with deformation in the Western area where we observe accumulations in structural and fault traps. In particular, the existing accumulations are well reproduced, and the model predicts favorable charge conditions for a prospect that is about to be drilled.

Importance Of Multi-Scale Petroleum System Assessment For Plays And Prospects De-Risking In The Eastern Mediterranean Basin.

Beicip-Franlab will present the following talk at AAPG GTW Alexandria, Egypt, September 2019

Pérez-Drago G¹, Dubille M¹, Montadert¹, Schneider F¹, Mouchot N¹, Chenet P¹, Callies M¹, Thebault A¹

1 Beicip-Franlab, Rueil-Malmaison, France

Abstract

Identifying the potential geological risks before drilling leads and prospects is a common practice for E&P operator companies. Traps and reservoir quality often receive the main attention during risk assessment. However, in the Eastern Mediterranean the biogenic gas sources generation, the synchrony between trap formation and hydrocarbon charge, and more important, the hydrocarbon preservation related to the large-scale hydrodynamics of the basin, are less analyzed or understood.

A key element in the Eastern Mediterranean mega basin is the assessment of the biogenic gas potential, both in term of generation but also of preservation in the geological system. The effectiveness of biogenic gas systems is mainly controlled by the past thermal gradients and sedimentation rates. Contrarily to conventional source rocks, significant rock volumes with low organic matter content are likely involved in the biogenic gas generation process. In the deepest parts of the basin, Tertiary biogenic gas source rocks are now undergoing catagenesis.

Another key element is the fluid flow history from the core of the Eastern Mediterranean basin toward its margins (including Eratosthenes Sea Mount). The hydrodynamics is first induced by high sedimentation rates and sediments compaction within the Nile Delta and the Levant Basin during the Oligo-Miocene and Plio-Pleistocene. During the Messinian Crisis short term 1400m sea level drop followed by massive impervious evaporite deposition plays a very important role in the evolution of fluid flow orientation, pressure gradients and hydrocarbon migration and dis-migration. The fluid flow is also controlled by the presence of a relatively well-connected pressure unit in Oligo-Miocene sands throughout the Levant Basin. Active hydrodynamism and buoyancy of biogenic gas are the main factors controlling the hydrocarbon migration mechanisms. A lateral long distance up-dip fill-and-spill migration is observed.

Therefore, a more complete understanding of the petroleum system behavior is achieved by recognizing the origin of the geochemical and physical phenomena occurring in the subsurface, in a regional or semi-regional basin scale. It will allow to recognize the hydrocarbon generation and the pore pressure and fluid flow regime patterns, which are not caught at limited prospect scale. Basin modeling techniques offer the possibility to estimate the heating rates of sedimentary basins, the timing and quantities of generation of biogenic or thermogenic hydrocarbons and, finally the pore pressure-effective stress regimes responsible, in part, for the hydrocarbon migration and effective charge.

Reducing Exploratory Risks Using Advanced Basin Modeling In a Complex Structural Setting – Parã-Maranhão Basin - Brazilian Equatorial Margin

Beicip-Franlab will present the following talk at AAPG ACE San Antonio, USA

Abstract
Felipe Nascimento1, Alcide Thebault², Marcia Kuhn Karam¹, Marie Callies², Eduardo de Mio¹
Queiroz Galvão Exploração e Produção, Rio de Janeiro, Brasil ¹
Beicip-Franlab, Rueil Malmaison, France ²

The Pará-Maranhão Basin is characterized as a passive margin basin with an orthogonal separation component related to the oblique opening of Equatorial Atlantic Margin during the Upper Albian.

The exploration efforts began in the middle seventies with few oil and gas discoveries from Cretaceous to Paleogene in shallow water. In the 2010´s decade, these efforts were moved from platform to deep water settings due to high resolution 3D seismic surveys that allowed the identification of potential hydrocarbon source rocks and well-developed channel-lobes turbidite systems rich in sandstones.

Those potential reservoirs were disconnected from slope to deep water settings by a gravity driven fold and thrust belt characterized by extensional, transitional and compressional domains which developed during Paleogene age. That disruption of the system was probably due to overloading caused by the deposition of a thick carbonate platform related to faults reactivation of the rift phase..

The main exploratory risks in this context are related to migration and charge issues due to structural complexity, the role of faults in migration and sealing, the effects of overloading in source rock maturation and expulsion timing, and the overpressure resultant of the material displacement.

The use of a new kinematic restoration tool, KronosFlow^TM, coupled with an unstructured mesh forward basin modeling tool (TemisFlow^TM), allowed the best prediction of the deformation timing, the evaluation of the synchronism between trap formation and hydrocarbon charge as well as the prediction of overpressure related to deformation and overloading.

Restoration results showed that the gravity driven system took place from Paleocene with the development of the listric growth fault systems in platform area and near slope, in the extensional domain. This imbricated fault system converges at the base to a detachment surface from Upper Albian. The evolution of this system from Eocene, with the overloading caused by sediment capture in roll-over systems triggered the rupture of the Santonian/Campanian sequences against a basement structural high and the beginning of the fold and thrust belt in the deepwater settings.

The timing of deformation and trap development improves the chance of charge from late source rock levels, as Turonian and Coniacian, believed to be present and mature in deep water settings in Pará-Maranhão Basin.

Beicip-Franlab will present the following talk at SPE Workshop, Bahrain 2019

The potential of foam-based injection processes for unlocking additional reserves in a giant fractured carbonate oil reservoir in the Middle East

Weber M¹.
1 Beicip-Franlab, Rueil-Malmaison, France

Abstract

Production of naturally fractured oil reservoirs is extremely challenging because of their adverse physics where viscous forces, which could be controlled, are inhibited and gravitational and capillary forces, which are inherent to the reservoir context and properties, are the only forces involved in oil recovery.
In fractured carbonate oil reservoirs, the typically strongly oil-wet character of rocks also prevents from implementing waterflooding techniques, leaving only gas injection and the associated Gas-Oil Gravity Drainage (GOGD) as a possible improved oil recovery technique beyond simple depletion scenarios. GOGD is however a slow process associated to limited ultimate oil recovery, and more advanced, enhanced oil recovery techniques should be considered in order to maximize oil production in such a context.
In this paper, we present the first step of an ambitious workflow aiming at unlocking the full potential of a giant fractured carbonate reservoir in the Middle East, which has yielded only about 25% of its oil in a 50-years production period, mostly by GOGD.
We test the potential of promising foam-based injection methods using a phenomenological flow simulation modeling approach at matrix block scale. In a first step, we describe the reservoir context and physical principles of our foam models. In a second step, we present encouraging flow simulation results indicating that (1) the foam injection processes tested allow improving the ultimate oil recovery in the blocks by several tens of percent compared with the GOGD case and, (2) that this incremental recovery is obtained with much improved kinetics, i.e. over a much shorter amount of time.
Finally, we discuss these results in terms of reservoir applicability and identify ways forward in order to de-risk the processes tested and pave the way to a future pilot implementation.

Beicip-Franlab will present the following talk at IAS Roma 2019 :

Importance of paleoenvironment reconstructions in geomodeling with scarce dataset: Cenomanian-Turonian carbonate platform from Northern Algeria

PRESENTED BY

Dr. Arnaud Fournillon (Beicip-Franlab)

AUTHORS

Dr. Arnaud Fournillon¹, Dr. Stefan Doublet¹, Dr. Jean-Marc Chautru¹, Ms. Naima Kherfi², Ms. Zahra Boudjemadi², Mr. Youcef Baba Ali² 

1. Beicip-Franlab
2. Sonatrach 

ABSTRACT

Upper Cretaceous from Northern Algeria is still a play under development. Most of structures are drilled with only few wells. In such condition, assessing the uncertainties and controlling the distribution of properties in undrilled areas is a key prerequisite for field development plans. We propose to integrate constraints from environment of deposition (EoD) reconstruction in order to improve the 3D geological models. This method is twofold with, firstly, a sedimentological study for defining the sedimentary sequences and building EoD maps. Secondly, geological modeling process, using these sequences and maps, is applied to compute a 3D trend cube of EoD on which is nested the distributions of reservoir properties. Volumetrics study shows the benefits of such methodology compared to direct interpolation/simulation of reservoir properties.

This study focuses on the Cenomanian and Turonian carbonate platform, covering the Ras Toumb and the upper part of the Zebbag formation. It consists in a rapid succession of carbonate, marls and shales over a thickness of around 300m. The reconstructed conceptual model of environment ranges from mud flat with fenestrae up to upper to lower offshore with calcisphere and planktic foraminifera mudstone/wackestone. In-between, shallow marine carbonate occurs characterized by grainstone/packstone with mollusks (including rudists), green algae and peloids.

Available dataset for the sedimentological study area is very scarce: only few wells, a single good quality core and scattered cuttings description, along with conventional logs. Consequently, the vertical resolution of the study has been limited to the cuttings description resolution. A continuous vertical curve of shallowing/deepening trend has been derived from the well-logs, tied with cuttings description, in order to overcome this issue. The studied interval has been represented by only five gross EoD maps, one per stratigraphic member, in order to limit the impact of low-resolution data. The full 3D cube of EoD is then derived by the integration of this vertical trend with EoD maps into a geomodelling software. This property cube enables the consistent representation of the rapid vertical transition, the conceptual geological model and the gross depositional environments per stratigraphic member. Stochastic simulations of reservoir properties, such as electrofacies and porosity, have been nested into this EoD cube.

Volumetric evaluations of hydrocarbons have been compared in order to assess the benefit of this method: firstly, a probabilistic Monte-Carlo approach has been applied in order to obtain a broad range of probable volumes; secondly, volume derived from direct stochastic simulation of properties has been compared to the volume obtained with paleoenvironmental constraints. Model without constraint has its volume around the P70 value, whereas the model with constraints is close to the P50 value.Thus, this method enables the control of stochastic simulation or interpolation in the extrapolated domain (faraway from hard data like wells) by the use of soft external (like EoD maps) data as trend. The scarcity of the dataset has been overcome by a careful management of resolution issues of all the available data.

General workflow from sedimentological and well data to volumetrics

Beicip-Franlab will present the following talk at EAGE Denmark 2018 :

Play Elements of the Chidley Basin, offshore Newfoundland and Labrador Canada

Erwan Le Guerroué¹, Paul Jermannaud¹, Pierre-Yves Filleaudeau¹, Guillermo Perez-Drago¹, Pierre-Yves Chenet¹ , Erin Gillis², Victoria Mitchell², Nicholas Montevecchi², Richard Wright²

1. Beicip-Franlab, Rueil-Malmaison, France.

2. Nalcor Energy, St. John's, NL, Canada.

Abstract

The underexplored Chidley Basin off the Labrador coast of Newfoundland Labrador, Canada is being investigated for oil and gas prospectivity after new seismic data acquisition.

We present here how the geology and geophysics data were integrated into a comprehensive 3D stratigraphic model which allowed the play elements of a potential petroleum system to be tested.

Regional geodynamic and sequence stratigraphic work facilitated the understanding of the basin architecture and infilling through the Labrador sea opening and transform fault zone activities. This provided the inputs of Gross Depositional Environment maps that ultimately enabled a forward stratigraphic model (DionisosFlow^®) to be built.

This forward numerical model simulates the stratigraphic record of the basin through calibration of well record and integration of seismic data. The model helps to resolve the extension of known, hypothetical, and/or speculative source rocks, reservoirs, carrier beds and seals at the basin scale.

Based on this regional stratigraphic understanding, the source rocks, reservoir, and seal presence seven main plays in the basin were identified, defining a complete petroleum system that shall be now tested offshore in the light of the past shelf discoveries.

Beicip-Franlab will present the following poster at AAPG Bolivia 2018 :

Stratigraphic and sedimentary processes simulation to explore the Silurian and Devonian sequence in the Madre de Dios basin

Djowan Thomas¹, Frederic Schneider¹, Stephane Rousse¹, Jean-luc Faure¹, Olvis Padilla², and Bertrand Valsardieu¹,  Jorge. Pareja²

¹Beicip-Franlab, 232 av. Napoleon Bonaparte, 92500 Rueil-malmaison, France; djowan.thomas@beicip.com

² YPFB;  Av. Grigotá Calle Regimiento Lanza, Santa Cruz, Bolivia

ABSTRACT

Petroleum exploration of frontier areas, such as the Madre de Dios basin, requires an innovative model based approach in order to lower the exploration risks. For this purpose, the DionisosFlow^® software has been used to explore the Silurian and Devonian stratigraphic sequence at regional scale and to determine if reservoirs observed at the wells location were likely to extend to the South where no well has been drilled.

The simulation of stratigraphic and sedimentary processes allowed to create a 3D geogrid predicting the internal stratigraphic architecture of the Silurian and Devonian series, consistent with well data, seismic and regional geological information. The geogrid includes reservoir distribution, sealing capacity and deposit environments.

Particularly, the resulting model has highlighted the presence of a large clinoform sequence during the middle Devonian period revealing a reservoir unit made of coastal to deltaic front sands extending toward the South of the basin. Such prograding sequence results from an uplift of about 200m where erosion and remobilization of sediment provided a large quantity of silico-clastic deposits to the south in deeper bathymetric area.

3D simulations of stratigraphic and sedimentary processes provided maps of net sand thickness and seal distribution all over the basin. A subtle tectonic event was identified defining a new potential play in the Madre de Dios basin originating from a mild regional structuration inducing structural traps. Additionally, the model provided a consistent stratigraphic chart for Silurian and Devonian period.

Beicip-Franlab will present the following poster at AAPG Bolivia 2018 :

Petroleum Systems Modeling and Hydrocarbon Charge Assessment in Pie De Monte Boomerang Province, Bolivia 

Guillermo Pérez-Drago¹, Frederic Schneider¹, Stephane Rousse¹, Jean-Luc Faure¹, Olvis Padilla² 

¹Beicip-Franlab, 232 av. Napoleon Bonaparte, 92500 Rueil-malmaison, France;

² YPFB;  Av. Grigotá Calle Regimiento Lanza, Santa Cruz, Bolivia

ABSTRACT

An active petroleum system is recognized by producing fields in Boomerang Pie de Monte foreland basin in stratigraphic up-dip and structural traps of Silurian-Devonian and Cretaceous formations. The area is considered as one of the most prolific gas provinces in Bolivia. However, the timing of hydrocarbon expulsion and migration versus trap formation remains unclear as confirmed by dry wells showing low gas shows of residual by-passed hydrocarbons.  

To reduce this uncertainty, we built a basin model that honors seismic structural interpretation and well data to simulate burial history, temperature, source rock maturity and pressure regimes through geological time. Hydrocarbon expulsion from source-rocks and further HC migration was simulated using 3D basin fluid flow modeling based on Darcy flow equation, followed by a map based fetch area trap charge assessment.

The main source rock units correspond to Silurian-Devonian sequences with influence of continental-marine environments (kerogen Type II/III). Maturity trend increases from north to south due to higher burial. Two phases of hydrocarbon expulsion were recognized: one early expulsion phase from Silurian source rocks during Late Triassic and a second expulsion phase from Early Devonian source rocks during Late Jurassic-Early-Cretaceous times.

Lateral long distance up-dip migration through Robore formation occurred before Andean deformation, following a northward fill and spill trap charge accumulating below Late Jurassic erosive unconformity. The Cretaceous plays were charged by vertical and lateral migration above the unconformity. The Andean deformation resulted in enhancing the structural closures and vertical migration towards Cretaceous plays.

The results of this study provided to YPFB a model based approach to predict yet to find volumes in place for undrilled prospects and leads and a proposition for a future drilling strategy.

Beicip-Franlab will present the following poster at AAPG Bolivia 2018 :

Probabilistic attribute derived from Pre-stack seismic inversion and characterization for prospect identification into Boomerang area.

Hermann Behira¹, Frédéric Schneider¹,Stephane Roussé¹, Donald Roccabruna¹, Olvis Padilla², Alcibiades Franco², and Bertrand Valsardieu¹

¹Beicip-Franlab, 232 av. Napoléon Bonaparte, 92500 Rueil-malmaison, France; hermann.behira@beicip.com

² YPFB;  Av. Grigotá Calle Regimiento Lanza, Santa Cruz, Bolivia

ABSTRACT

In the prospect evaluation work performed in Boomerang area, the uncertainty on the estimation of the hydrocarbon occurrence derived from seismic data has been a major importance in the exploration of this area. For this purpose, a dedicated workflow using Interwell^™ and Easytrace^™ integrating geological, petrophysical and seismic data has been applied to constrain petrophysical property distribution using elastic inversion.

Initially, a detailed petro-elastic analysis was performed on the well near the prospect in order to define the relationships between petrophysical properties and elastic parameters (P and S velocity). Then, the available pre-stack seismic data were inverted using a stratigraphic inversion methodology prior to be used in a discriminant analysis to predict the presence of hydrocarbon and the probability associated. 

Therefore, both software provided a solution combining seismic inversion and seismic characterization to predict specific seismic facies distribution (including HC bearing facies) and associated probabilities for the entire seismic grid. The probabilistic attribute was helpful to evaluate the geological chances of success for finding HC in the prospect.