|Title||A petroleum resource assessment of the Huron Domain area, southern Ontario|
|Licence||Please note the adoption of the Open Government Licence - Canada
supersedes any previous licences.|
Hannigan, P; Carter, T R; Liu, X; Crowe, R; Obermajer,
|Source||Geological Survey of Canada, Open File 8784, 2021, 59 pages, https://doi.org/10.4095/328193 Open Access|
|Publisher||Natural Resources Canada|
|NTS||30M/13; 31D/04; 31D/05; 31D/12; 40P/05; 40P/06; 40P/07; 40P/09; 40P/10; 40P/11; 40P/12; 40P/13; 40P/14; 40P/15; 40P/16; 41A/01; 41A/02; 41A/03; 41A/04; 41A/05; 41A/06; 41A/07; 41A/08; 41A/09; 41A/10;
|Area||Huron County; Perth County; Bruce County; Dufferin County; Grey County; Wellington County; Simcoe County; Waterloo County|
|Lat/Long WENS|| -82.5000 -79.7500 44.7500 43.4167|
|Subjects||fossil fuels; stratigraphy; sedimentology; structural geology; geochemistry; geophysics; Science and Technology; Nature and Environment; petroleum resources; resource estimation; hydrocarbon potential;
hydrocarbons; gas; oil; Upper Ordovician; reservoir rocks; bedrock geology; lithology; sedimentary rocks; shales; carbonates; structural features; faults; fractures; porosity; permeability; source rocks; hydrocarbon migration; models; formation
pressures; thermal maturation; oil viscosities; lithostratigraphy; isopachs; organic geochemistry; organic carbon; reservoir parameters; well logging; structural controls; Huron Domain; Blue Mountain Formation; Rouge River Member; Cobourg/Lindsay
Formation; Collingwood Member; Appalachian Basin; Michigan Basin; Salina Group; Lockport Group; Guelph Formation; Trenton Group; Black River Group; Phanerozoic; Paleozoic; Silurian; Ordovician|
|Illustrations||geoscientific sketch maps; stratigraphic charts; well logs; models; flow diagrams; plots; profiles; photographs; histograms; tables|
|Program||Energy Geoscience |
|Released||2021 04 01 (16:00)|
|Abstract||The Geological Survey of Canada has quantitatively assessed oil and gas resources in self-sourced and self-retained fine-grained clastic (shale) reservoirs within the Upper Ordovician Collingwood and
Rouge River members, as well as the undiscovered potential oil and gas resources in Paleozoic conventional reservoirs, incorporating data from a site formerly proposed for a Low and Intermediate deep geologic repository and regional data from
southern Ontario. If these two Upper Ordovician shale units are treated as separate resource plays, both fail to meet the minimum criteria set out by the United States Geological Survey (USGS) that define a hydrocarbon resource play. When combined
however, the two units can be treated as a continuous sedimentary package and, therefore, can be treated as a single resource play.|
In this report, only the technically recoverable resources are reported. Technically recoverable resources are
defined as the volume of oil and gas that could be produced with technology available at the time of the present report, regardless of commodity price, production cost and the cost of bringing the products to markets.
The cut-off for the
volumetric calculation is 0.5 meters of cumulative hydrocarbon-saturated rock column, which is calculated from hydrocarbon saturated porosity times gross thickness of the combined Collingwood and Rouge River shale units. The 0.5 meter cut-off is
equivalent to a hydrocarbon saturated porosity >2.5% and combined gross thickness >20 meters. The cut-off is in general consistent with the geological criteria for defining the shale play boundary as described by the USGS and mentioned above. The
total area defined by the reservoir cut-off is smaller than the area within the shale play boundary and is regarded as the risked prospective area by reservoir criterion.
The geographic distribution of the predicted hydrocarbon resources of the
Upper Ordovician Collingwood and Rouge River shale units indicates that a large volume of the potential hydrocarbon resources of these two shale units occur in the Appalachian Basin portion of southern Ontario. Only a small quantity of the
reservoir-risked resource is predicted to occur in the southeastern part of the Nuclear Waste Management Organization (NWMO) study area.
Among the undiscovered technically recoverable unconventional resources within the study area, the mean totals
are 11.7 million barrels of shale oil (MMBO), with a fractile (F95-F05, respectively) range from 6.4-19.2 MMBO and 8.0 billion cubic feet of continuous gas (Bcf), with a fractile range from 4.6-12.7 Bcf. Regarding conventional resource, mean totals
of 6.8 million barrels of conventional oil and 52.3 Bcf of conventional gas are estimated to occur in the study area, although subjectively this estimate is considered to be optimistic.
The ranges of resource estimates reflect the geologic
uncertainty of the source-reservoir rock systems and spatial extrapolation of resource mapping from sparse well controls. Much of the uncertainty is related to models constructed to estimate the quantity of oil remaining in the source rocks following
migration and the quality of oil and gas stored in conventional reservoirs. Only a small portion of the potential resource lies within the NWMO study area (Huron Domain). The bulk of the potential hydrocarbons that are estimated to be trapped within
the lithostratigraphic members is considered to be exceptionally low in the NWMO study area due to a combination of low permeability, contrasting lithologies, low formation pressures, low degrees of thermal maturation, high oil viscosity impeding
hydrocarbon fluid flow and poor oil show index (S1/TOC <1).
|Summary||(Plain Language Summary, not published)|
The Geological Survey of Canada has quantitatively assessed oil and gas resources in shale reservoirs in the Upper Ordovician Collingwood and Rouge River
members, as well as the undiscovered oil and gas resource in Paleozoic conventional reservoirs incorporating data from a site formerly proposed for a Low and Intermediate deep geologic repository and regional data from southern Ontario. Among the
undiscovered technically recoverable unconventional resources within the study area, the mean totals are 11.7 million barrels of shale oil (MMBO), with a fractile (F95-F05, respectively) range from 6.4-19.2 MMBO, and 8.0 billion cubic feet of
continuous gas (BCFG), with a fractile range from 4.6-12.7 BCFG. Regarding conventional resources, mean totals of 6.8 million barrels of conventional oil and 52.3 BCFG of conventional gas are expected to occur in the study area.