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...

Poster · April 2016 DOI: 10.13140/RG.2.1.4506.9201

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Pauthier Stanislas Benoit Chauveau IFP Energies nouvelles IFP Energies nouvelles

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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

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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 biological conditions Sedimentation rate  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.

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- 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 Nordegg Formation (right). Results show that, for both the Montney and Nordegg Formations, Organic porosity can represent maturity ranges from immature at the unconformity edge in the NE to as much as 28% of the porosity gas window in the deep basin close to deformation front in the SW (Fig. in the Montney Fm. (Fig. 12 left). 10). A wide area of the Nordegg Formation, one of the main source of Its compaction depends on conventional accumulations is in the oil window. burial and maturity evolution. Adsorption plays a key role on gas retention into the source rock as The Nordegg Fm. (Type II/IIS), adsorbed gas represent more than 20% of gas in place even in deeper more reactive, is more affected and more mature areas of the Montney Fm. (Fig. 11). than the Montney Fm. (Fig. 13).

Fig. 13: Evotution of organic porosity as a function of SR maturity Conclusions  New methods were applied to better characterize and predict key controlling factors such as organic matter distribution, paleo-heat flow and retention mechanisms.  Mechanisms specific to hydrocarbon retention (adsorption, organic porosity) were simulated and improved (organic porosity compaction) for better petroleum systems analysis. . More predictive source rock and maturity distributions for a better analysis of sweet spots . Better HC expulsion towards conventional reservoirs (strong compaction of organic porosity in the Nordegg Fm.) . Strong contribution of organic porosity and adsorption on HC retention in the Montney Fm.  First 4D basin model of the WCSB covering both Alberta and British Columbia for assessment of conventional and unconventional petroleum resources.

Perspectives  Stratigraphic models including carbonates, silici-clastic and organic matter deposition  Migration and natural hydraulic fracturation (Fig. 14)  Hydrocarbon alterations (TSR, biodegradation…)

 Mapping of sweet spots using cutting edge probabilistic techniques

All information available on the Joint Industry Project RAMPS on prospect analysis of the WCSB Fig. 14: HC saturation (%) pervasive gas accumulations

(Contact: [email protected] or [email protected]) in the tight reservoirs of the Montney Fm.

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