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Modeling Source Rock Distribution, Thermal Maturation, Petroleum Retention and Expulsion: the Case of the Western

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Modeling Source Rock Distribution, Thermal Maturation, Petroleum Retention and Expulsion: the Case of the Western See discussions, stats, and author profiles for this publication at: https://www.researchgate.net/publication/301200555 Modeling source rock distribution, thermal maturation, petroleum retention and expulsion: The Case of the Western... Poster · April 2016 DOI: 10.13140/RG.2.1.4506.9201 CITATIONS READS 0 172 5 authors, including: Pauthier Stanislas Benoit Chauveau IFP Energies nouvelles IFP Energies nouvelles 6 PUBLICATIONS 1 CITATION 28 PUBLICATIONS 27 CITATIONS SEE PROFILE SEE PROFILE Tristan Euzen W. Sassi ifp technologies (Canada) Inc., Calgary, Canada IFP Energies nouvelles 49 PUBLICATIONS 116 CITATIONS 75 PUBLICATIONS 1,181 CITATIONS SEE PROFILE SEE PROFILE Some of the authors of this publication are also working on these related projects: Biogenic Gas Modeling View project Mechanical model of fractured hydrocarbon reservoirs View project All content following this page was uploaded by Mathieu Ducros on 11 April 2016. The user has requested enhancement of the downloaded file. Renewable energies | Eco-friendly production | Innovative transport | Eco-efficient processes | Sustainable resources Modeling source rock distribution, thermal maturation, petroleum retention and expulsion: The Case of the Western Canadian Sedimentary Basin (WCSB) Stanislas Pauthier1, Mathieu Ducros1, Benoit Chauveau1, Tristan Euzen2, William Sassi1 1 IFP Énergies nouvelles, Geosciences Division, Rueil Malmaison, France 2 IFP Technologies (Canada) Inc., Calgary, AB, Canada. Contact: [email protected] Introduction Basin modeling is a multi-disciplinary approach We present solutions that allow to produce integrating varied sources of geological data. calibrated and geologically meaningful maps of Therefore, the main objective is to build models heat flow, initial TOC and hydrogen index based on consistent with the available information. both well measurements and on the geological information included in the basin model. For instance, input parameters such as heat flow and initial TOC must be first calibrated at the They are applied on a large scale basin model of location of wells and extrapolated on maps taking the WCSB (800km x 1300km) using TemisFlow® into account available geological, biological or (Fig. 1). A focus is done on the Montney and Fig. 1: 3D model of the Western Canadian Sedimentary Basin. geochemical concepts. Nordegg source rocks intervals and on the (34 stratigraphic units with a 5km cell resolution). unconventional petroleum system of the Montney Formation. Fig. 2: Location of the simulated 3D and 2D models in the Western Canadian Sedimentary Basin Geological settings of the WCSB Foreland basin limited to the East by the Precambrian Canadian Shield and to the West by the Canadian Cordillera (Fig. 2). 3 major periods: . Paleozoic to early Mesozoic time: sedimentation on the western margin of a stable craton dominated by carbonate deposits. Jurassic to Paleocene: clastic sedimentary wedge induced by the formation of the Cordillera and its associated foreland basin. From Paleocene onward: Erosion and sediment by-pass (Laramide Orogeny). Focus on Montney and Doig Formations (Fig. 3): . Siliciclastic sediments of the Triassic succession. They rest unconformably on the Permian Belloy Formation. The Upper boundary of the Triassic is a major unconformity related to the formation of the Canadian Cordillera. TOC0,HI0 . In the Eastern part, they are capped by the organic-rich shale of the Nordegg Formation. In the Western part, they are overlaid by the proximal sandy deposits of the Middle Triassic Halfway Formation. Fig. 3: Cross section presenting the main stratigraphic intervals of the WCSB. Methodology and modeling workflow Petroleum retention (organic Pressure , migration porosity, adsorption) and HC alteration and expulsion Geological 4D model Source rock maturity Conventional and unconventional (facies, bathymetry, thickness and Uncertainty petroleum systems analysis sedimentation rate, well data, …) and risk IFP Energies nouvelles Energies IFP - © 2012 2012 © Renewable energies | Eco-friendly production | Innovative transport | Eco-efficient processes | Sustainable resources Source rock richness at basin scale PP0: primary productivity Ox0: basin scale redox Chemical and conditions biological conditions TOCPD: present day TOC Very prolific basin (Ox0, PP0) HIPD: present day HI Duvernay (Devonian, Type II) TOCOS: simulated initial TOC HIOS: simulated initial HI Simulation of TOC and HI at wells locations Exshaw-Bakken (Devonian, Type II 0 0 TOCOC: computed initial TOC (TOC0S, HI0S) = function( Montney (Triassic, Type II) sedimentation rate bathymetry Sedimentation rate biological conditions Phosphatic Doig (Triassic, Type IIS) and bathymetry Nordegg-Gordondale (Jurassic, Type IIS) chemical conditions ) Optimization Poker Chip (Jurassic, Type II) HIOs of (Ox0, PP0) Mannville Coals (Cretaceous, Type III) Computation of TOC0C TOC OC TOCPD and HIPD Estimation of initial SR potential TOCOC Estimation of initial TOC (TOC ) and HI (HI ) maps of Computation of the error function 0 0 Error = function(TOC – TOC ) marine organic matters is performed based on 0S 0S geological and biological considerations (Fig. 5). Inputs: Optimized Sedimentation rate and bathymetry maps Modern TOC and HI measured at wells (PP0, Ox0) Paleobathymetry Computation SR distribution Fig. 5: Forward model for estimation of TOC0 and HI0 of Sedimentation rate. and richness at basin scale from marine organic matter (MOM) as a result of Outputs: primary productivity (PP0) and degradation processes. Degradation along the water column is estimated from Estimated TOC0 and HI0 at well locations. Fig. 4: Estimation of TOC0 and HI0 maps consists in two main steps: Martin’s law (1987): the effective organic flux of organic Maps of TOC and HI at basin scale. • An optimization of the biological (PP0) and chemical conditions 0 0 matter (PPz) at the water/sediments interface is a (Ox0) using well data. function of the bathymetry and of the primary • An extrapolation to basin scale based on the maps of bathymetry, productivity (PP0). Finally, early diagenesis is estimated and sedimentation rate and on the optimized PP0 and Ox0. from the burial efficiency (i.e. sedimentation rate and redox conditions, Burdige , 2007) Focusing on the Montney and Nordegg Formations • Type II (low TOC and oxic conditions) • Calibration from 7 wells Formation Montney Sedimentation rate Bathymetry TOC0 HI0 (m/My) (m) (%) (mgHC/gC) • Type II/IIS (high TOC and anoxic conditions) • Calibration from 34 wells Formation Nordegg Fig. 6: Geological settings associated to the deposition of the Nordegg Fig. 7: Initial source rock richness (TOC0 and HI0) of the Montney and and Montney organic-rich Formations. The Montney Formation exhibits, Nordegg Formations. Dilution processes strongly control The relatively to source rocks, high sedimentation rates (from 20m/My to Montney Formation initial richness (TOC0, top left), while the richness more than 60m/My, top left) whereas low sedimentation rates (<5m/My) of the Nordegg Formation is more strongly controlled by characterize the Nordegg Formation (bottom left). paleobathymetry (bottom left). References Burdige, D. J.(2007). Preservation of Organic Matter in Marine Sediments: Controls, Mechanisms, and an Imbalance in Sediment Organic Carbon Budgets? Chem. Rev., 107, pp. 467-485 Crombez, V., PhD Thesis, 2016. Ducros, M., Euzen, T., Crombez, V., Sassi, W. and Vially, R., 2016, 2-D basin modeling of the WCSB across the Montney-Doig system: implications for hydrocarbon migration pathways and unconventional resources potential, AAPG Memoir. IFP Energies nouvelles Energies IFP - Martin, J.H., Knauer, G.A., Karl, D.M., Broenkow, W.W., 1987, VERTEX: carbon cycling in the northeast Pacific. Deep-Sea Res. 34: 267-285. Mossop, G.D. and Shetsen, I., 1994. Geological atlas of the Western Canada Sedimentary Basin. Canadian Society of Petroleum Geologists and Alberta Research Council Romero-Sarmiento, M.F., Ducros, M., Carpentier, B., Lorant, F., Cacas, M.C., Pegaz-Fiornet, S., Wolf, S., Rohais, S. and Moretti, I., 2013, Quantitative evaluation of TOC, © 2012 2012 © organic porosity and gas retention distribution in a gas shale play using petroleum system modelling: Application to the Mississippian Barnett Shale. Marine and Petroleum Geology, 45, 315-330. Renewable energies | Eco-friendly production | Innovative transport | Eco-efficient processes | Sustainable resources Petroleum System modeling Thermal calibration method It aims at taking the best of the geological knowledge, synthetized in a b the geological model, and of automated well calibration: Finally both information is combined to provide geologically constrained heat flow maps calibrated at well locations (Fig. 9b). Heat flow in time and space (Fig. 9a) representative of the Crust + sediments Crust geology (heterogeneities, 3D simulation including the blanketing and tectonic sedimentary and crustal models effects…) Automated well calibration Fig. 8: Workflow of thermal calibration. Fig. 9: Present day heat flow maps before (a) and after calibration (b). Source rock maturity, petroleum retention and expulsion Maturity Adsorption Organic porosity creation and compaction Fig. 10: Maturity maps (VRo%) of the Montney (left) and Fig. 11: Fraction of adsorbed gas Fig. 12: Fraction of organic porosity in the Montney Formation (left). Nordegg Formations (right) in the Montney Formation Fraction of expelled oil resulting from organic porosity compaction (center) and expelled oil mass (kg/m²) in the
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