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Oil-and gas-prone source rock is identified and an assessment is made of original
hydrocarbon potential for mature source rocks. The number of genetically distinct
oil families (sources) existing in the area is determined, as well as probable migration
pathways, thermal maturity and type/degree of alteration. Services offered include
Source Rock Evaluation, Gas, Condensate, Crude Oil, and Oil Seep Characterization
and Reservoir Geochemistry Analyses.
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Source Rock Evaluation
These analyses define the richness, type (oil/gas) and thermal maturity of organic
matter in cuttings, core or outcrop in order to evaluate potential source rocks.
Samples are first screened with TOC analyses, followed by Rock-Eval Pyrolysis. Samples
passing the initial screen proceed for Kerogen Microscopy and Extract Analyses.
The Kerogen Analyses assesses the type of material present, Vitrinite Reflectance
(VR) and Thermal Alteration Index (TAI). The extract work is performed on saturated
and aromatic fractions of bitumens extracted from the sample and includes quantification
and compositional analyses using GC, GC/MS and C Isotope techniques.
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Hydrocarbon (gas, condensate, crude oil and oil-seep) Characterisation
For hydrocarbon gases these data provide information on the composition and
origin of the gas. For liquid hydrocarbons oil quality is assessed, the source type
identified along with the level of thermal maturity and nature of any alteration
processes. These data are also used in oil-oil, oil-condensate, oil-seep correlations
and reservoir continuity studies. Techniques include Gas Chromatography (GC) and
Stable Isotope Ratio determinations, whole-oil GC, Liquid Chromatographic (LC) Separation
and GC-MS of saturate and aromatic fractions.
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Reservoir Geochemistry
These analyses allow the identification and delineation of producing intervals and
definition of contacts, and assist in defining vertical and lateral reservoir continuity
and an understanding of reservoir compartmentalization. The data may also be used
for production allocation in commingled or multi-zone scenarios or to improve understanding
of reservoir filling history. The standard technique involves oil fingerprinting
including measurement of napthenic and aromatic peak pairs that provides the data
for the ratio calculations used to assess the degree of similarity of companion
oils.
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