GEOSCAN Search Results: Fastlink

GEOSCAN Menu


TitleOrganic matter characterization in mixed hydrocarbon producing areas within the Duvernay Formation, Western Canada Sedimentary Basin, Alberta
AuthorVan de Wetering, N; Sanei, H; Mayer, B
SourceInternational Journal of Coal Geology vol. 156, 2016 p. 1-11, https://doi.org/10.1016/j.coal.2016.01.012
Year2016
Alt SeriesEarth Sciences Sector, Contribution Series 20140431
PublisherElsevier
Documentserial
Lang.English
Mediapaper; on-line; digital
File formatpdf
ProvinceAlberta
Lat/Long WENS-118.0000 -116.0000 55.0000 53.0000
Subjectsoil; gas; organic materials; kerogen; source rocks; vitrinite reflectance; thermal maturation; Duvernay Shale; Rock-Eval; organic petrology; Devonian
Illustrationslocation maps; schematic cross-sections; tables; graphs; photomicrographs
ProgramShale Reservoir Characterization, Geoscience for New Energy Supply (GNES)
AbstractThis paper characterizes organic matter in the mixed hydrocarbon (oil-dry gas, oil-condensate) producing areas of the Late Devonian Duvernay Formation in Alberta (Canada) by high-resolution RockEval data (n = 246) and petrography (n = 35) at three drillhole locations (Locations A and C distal, Location B proximal to Leduc Reef, respectively). Total organic carbon (TOC) ranges from 0.15 - 6.22 wt.% at Location A, 0.43 - 8.20 wt.% at Location B, and 1.84 - 5.23 wt.% at Location C with an overall median value of 3.42 wt.%. S2 values range from 0.20 - 7.42 mg HC/g of rock at Location A, 0.22 - 4.23 mg HC/g of rock at Location B, and 1.68 - 5.04 mg HC/g of rock at Location C. These results for samples from Locations A, B and C indicate that kerogen is Type I to Type II. The hydrogen index (HI) of these rocks is significantly lower (< 160 mg HC/g TOC) than that of traditional oil-producing source rocks of this age (~400 - 700 mg HC/g TOC). At Locations A and C, Tmax lies within the oil window with a mean value of 459 °C; at Location B, Tmax varies greatly between 434 and 488 °C, between the oil and gas window, with no observable association with sample depth. Vitrinite reflectance of samples ranges from 0.99 - 1.32%. Tmax values do not correlate with vitrinite reflectance of the samples (R2 = 0.04), nor with depth (R2 = 0.4), suggesting that Tmax is not a reliable indicator of thermal maturity in this system. Low TOC/S2, high mineral carbon is associated with intervals of intergrown sparry calcite and pyrite in petrographic samples at Location B. Organic matter within the Duvernay Formation was characterized as almost entirely solid bitumens, with very minor inertinite, < 1% by volume). The RockEval and petrographic observations suggest that secondary diagenetic effects are the cause for the mixed hydrocarbon signature, rather than any spatial variation in depositional environment or thermal maturation regimes.
Summary(Plain Language Summary, not published)
This paper provides new and important data about the rock composition, hydrocarbon potential, and fertility of Duvernay shale gas.
GEOSCAN ID295818