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Seediscussions,stats,andauthorprofilesforthispublicationat:https://www.researchgate.net/publication/301200555
Modelingsourcerockdistribution,thermalmaturation,petroleumretentionandexpulsion:TheCaseoftheWestern...
Poster·April2016
DOI:10.13140/RG.2.1.4506.9201
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Modeling source rock distribution, thermal maturation, petroleum retention and expulsion: The Case of the Western Canadian Sedimentary Basin (WCSB)
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.
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.
Introduction Basin modeling is a multi-disciplinary approach
integrating varied sources of geological data.
Therefore, the main objective is to build models
consistent with the available information.
For instance, input parameters such as heat flow
and initial TOC must be first calibrated at the
location of wells and extrapolated on maps taking
into account available geological, biological or
geochemical concepts.
We present solutions that allow to produce
calibrated and geologically meaningful maps of
heat flow, initial TOC and hydrogen index based on
both well measurements and on the geological
information included in the basin model.
They are applied on a large scale basin model of
the WCSB (800km x 1300km) using TemisFlow®
(Fig. 1). A focus is done on the Montney and
Nordegg source rocks intervals and on the
unconventional petroleum system of the Montney
Formation.
Fig. 3: Cross section presenting the main stratigraphic intervals of the WCSB.
Fig. 1: 3D model of the Western Canadian Sedimentary Basin.
(34 stratigraphic units with a 5km cell resolution).
Fig. 2: Location of the simulated 3D and 2D models
in the Western Canadian Sedimentary Basin
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]
Methodology and modeling workflow
TOC0,HI0
Geological 4D model
(facies, bathymetry, thickness and
sedimentation rate, well data, …)
Source rock maturity
Petroleum retention (organic
porosity, adsorption)
and expulsion
Conventional and unconventional
petroleum systems analysis
Pressure , migration
and HC alteration
Uncertainty
and risk
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Very prolific basin Duvernay (Devonian, Type II)
Exshaw-Bakken (Devonian, Type II
Montney (Triassic, Type II)
Phosphatic Doig (Triassic, Type IIS)
Nordegg-Gordondale (Jurassic, Type IIS)
Poker Chip (Jurassic, Type II)
Mannville Coals (Cretaceous, Type III)
Estimation of initial SR potential Estimation of initial TOC (TOC0) and HI (HI0) maps of
marine organic matters is performed based on
geological and biological considerations (Fig. 5).
Inputs:
Modern TOC and HI measured at wells
Paleobathymetry
Sedimentation rate.
Outputs:
Estimated TOC0 and HI0 at well locations.
Maps of TOC0 and HI0 at basin scale.
Fig. 5: Forward model for estimation of TOC0 and HI0 of
from marine organic matter (MOM) as a result of
primary productivity (PP0) and degradation processes.
Degradation along the water column is estimated from
Martin’s law (1987): the effective organic flux of organic
matter (PPz) at the water/sediments interface is a
function of the bathymetry and of the primary
productivity (PP0). Finally, early diagenesis is estimated
from the burial efficiency (i.e. sedimentation rate and
redox conditions, Burdige , 2007)
Fig. 4: Estimation of TOC0 and HI0 maps consists in two main steps:
• An optimization of the biological (PP0) and chemical conditions
(Ox0) using well data.
• An extrapolation to basin scale based on the maps of bathymetry,
and sedimentation rate and on the optimized PP0 and Ox0.
Fig. 7: Initial source rock richness (TOC0 and HI0) of the Montney and
Nordegg Formations. Dilution processes strongly control The
Montney Formation initial richness (TOC0, top left), while the richness
of the Nordegg Formation is more strongly controlled by
paleobathymetry (bottom left).
Fig. 6: Geological settings associated to the deposition of the Nordegg
and Montney organic-rich Formations. The Montney Formation exhibits,
relatively to source rocks, high sedimentation rates (from 20m/My to
more than 60m/My, top left) whereas low sedimentation rates (<5m/My)
characterize the Nordegg Formation (bottom left).
Sedimentation rate
(m/My)
Bathymetry
(m)
TOC0
(%)
HI0
(mgHC/gC)
Mo
ntn
ey F
orm
ati
on
N
ord
eg
g F
orm
ati
on
Focusing on the Montney and Nordegg Formations
• Type II (low TOC and
oxic conditions)
• Calibration from 7 wells
• Type II/IIS (high TOC
and anoxic conditions)
• Calibration from 34
wells
Source rock richness at basin scale
TOCPD and HIPD
Chemical and biological conditions
(Ox0, PP0)
Simulation of TOC0 and HI0 at wells locations (TOC0S, HI0S) = function( sedimentation rate bathymetry biological conditions chemical conditions )
Computation of TOC0C
Computation of the error function Error = function(TOC0S – TOC0S)
Sedimentation rate and bathymetry
TOCOC
Optimization of (Ox0, PP0)
PP0: primary productivity Ox0: basin scale redox conditions TOCPD: present day TOC HIPD: present day HI TOCOS: simulated initial TOC HIOS: simulated initial HI TOCOC: computed initial TOC
Optimized (PP0, Ox0)
Sedimentation rate and bathymetry maps
Computation SR distribution and richness at basin scale
HIOs
TOCOC
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.
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,
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.
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Thermal calibration method It aims at taking the best of the geological knowledge, synthetized in
the geological model, and of automated well calibration:
Fig. 9: Present day heat flow maps before (a) and after calibration (b).
a b
Cru
st
+ s
ed
ime
nts
3D simulation including the
sedimentary and crustal models
Heat flow in time and space
(Fig. 9a) representative of the
geology (heterogeneities,
blanketing and tectonic
effects…)
Automated
well calibration
Finally both information is
combined to provide
geologically constrained heat
flow maps calibrated at well
locations (Fig. 9b).
Petroleum System modeling
Source rock maturity, petroleum retention and expulsion
Organic porosity creation and compaction
Organic porosity can represent
as much as 28% of the porosity
in the Montney Fm. (Fig. 12 left).
Its compaction depends on
burial and maturity evolution.
The Nordegg Fm. (Type II/IIS),
more reactive, is more affected
than the Montney Fm. (Fig. 13).
Adsorption
Maturity
Fig. 10: Maturity maps (VRo%) of the Montney (left) and
Nordegg Formations (right)
Fig. 11: Fraction of adsorbed gas
in the Montney Formation
Fig. 12: Fraction of organic porosity in the Montney Formation (left).
Fraction of expelled oil resulting from organic porosity compaction (center)
and expelled oil mass (kg/m²) in the Nordegg Formation (right).
Fig. 8: Workflow of thermal calibration.
Fig. 13: Evotution of organic porosity as a function of SR maturity
Results show that, for both the Montney and Nordegg Formations,
maturity ranges from immature at the unconformity edge in the NE to
gas window in the deep basin close to deformation front in the SW (Fig.
10). A wide area of the Nordegg Formation, one of the main source of
conventional accumulations is in the oil window.
Adsorption plays a key role on gas retention into the source rock as
adsorbed gas represent more than 20% of gas in place even in deeper
and more mature areas of the Montney Fm. (Fig. 11).
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
(Contact: [email protected] or [email protected]) Fig. 14: HC saturation (%) pervasive gas accumulations
in the tight reservoirs of the Montney Fm.
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