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TitleHydrocarbon potential and depositional environment of the Lower Cretaceous Garbutt Formation, Liard Basin, Canada
AuthorHaeri-Ardakani, O; Sanei, H; McMechan, M; Van de Wetering, N; Reyes, J; Ferri, F
SourceCSPG Geoconvention 2015: New Horizons, abstracts; Canadian Society of Petroleum Geologists, Canadian Society of Exploration Geophysicists, Joint Annual Meeting, Abstracts 2015 p. 1-4
Alt SeriesEarth Sciences Sector, Contribution Series 20140399
MeetingCSPG Geoconvention 2015; Calgary; CA; May 4-8, 2015
File formatpdf
ProvinceBritish Columbia
NTS94I/11; 94I/12; 94I/13; 94I/14; 94J/09; 94J/10; 94J/11; 94J/12; 94J/13; 94J/14; 94J/15; 94J/16; 94K/09; 94K/10; 94K/15; 94K/16; 94N; 94O; 94P/03; 94P/04; 94P/05; 94P/06; 94P/11; 94P/12; 94P/13; 94P/14
AreaFort Nelson River
Lat/Long WENS-126.0000 -121.0000 60.0000 58.2500
Subjectsfossil fuels; stratigraphy; hydrocarbons; hydrocarbon potential; depositional environment; Lower Cretaceous; Liard Basin; Garbutt Formation; Mesozoic; Cretaceous
Illustrationslocation maps
ProgramShale Reservoir Characterization, Geoscience for New Energy Supply (GNES)
ProgramProgram of Energy Research and Development (PERD)
LinksOnline - En ligne
This study presents organic matter (OM) characterization, thermal maturity, hydrocarbon potential and paleo-redox sedimentary conditions of the Lower Cretaceous Garbutt Formation in the Liard Basin in British Columbia. The study compares outcrop samples from western edge of the basin to subsurface core samples from the eastern margin. Lower Garbutt lithology varies from coarse-grained siltstone (mean = 51.9?m) in the west to shaley facies in the eastern part of the basin. The major OM constituents of western outcrop samples are vitrinite and inertinite macerals (kerogen Type III) that are mainly reworked. Minor amounts of migrabitumen have filled intergranular porosities. In contrast core samples from near the eastern basin margin consist of kerogen Type II, dominantly composed of liptinite group macerals (alginite) with lower abundance of vitrinite and intertinite group macerals. Total organic carbon (TOC) content of outcrop samples is significantly lower (mean: 1.21 wt. %) than subsurface core samples (mean: 4.2 wt. %). Outcrop samples are at the end of oil window while the maturation of core samples varies from onset of the oil window to the condensate zone with a gradual north to south increase in thermal maturity. Intercrystalline porosity associated with framboidal pyrite and microfossil interskeletal porosity host free oil in the core samples, whereas, intergranular porosity forms the major pore spaces in silty outcrop samples. These results indicate that the Garbutt Formation near the eastern margin of the Liard Basin in British Columbia could potentially be an excellent target for unconventional oil and wet gas exploration. Paleo-redox trace element (i.e., Mo and U) enrichment factor (EF) of subsurface samples relative to average shale is higher by two orders of magnitude. In contrast outcrop samples have no significant EF. The predominance of terrestrial OM (kerogen Type III), coarser grain size, and higher detrital mineral contents of outcrop samples in comparison to the mainly marine OM (kerogen Type II, liptinite group), finer grain sediments and significantly higher TOC content and paleo-redox trace elements concentrations suggest the primary source of sediment for the Garbutt Formation was from the west. The trace elements record of core samples show small scale variation in the basin redox condition.
Summary(Plain Language Summary, not published)
This conference presentation describes organic geochemistry results from outcrop and subsurface samples of the Lower Cretaceous Garbutt Formation from the western and eastern parts of Liard Basin in British Columbia.