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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.
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.
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.
 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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