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After SARA, the saturate fraction can be analyzed in much more detail using gas chromatography (GC) and gas chromatography combined with mass spectrometry (GC-MS), which separate the saturate fraction into individual molecular components.
GC-MS analysis can also be performed on the aromatic fraction, if desired.
Carbon-isotope ratios can be measured on the whole oil, on any of the SARA fractions, and even on individual compounds. This latter analysis is not common, and is usually limited to the n-alkanes and isoprenoids.
The data from these analyses that characterize an oil can then be used in a number of ways: to help define the organofacies from which the oil was generated; to help estimate which layer is likely to be the source rock; to estimate maturity of the oil; to correlate this oil with other oils, permitting us to divide a group of oils into different oil families, subfamilies, and mixtures, and to correlate oils with their suspected or proposed source rocks. We recommend Biomarkers for Geologists (Waples and Machihara, 1991) and The Biomarker Guide (Peters et al., 2005) as valuable references for interpreting these data.
Correlations are comparisons of the properties of two or more samples. Oils can be correlated with other oils, or with source rocks. The objectives of oil correlations are to establish genetic relationships among the samples, which in turn permit us to divide a group of oil samples into families or subfamilies; or to establish a positive or negative genetic relationship between an oil and a suspected source rock.
Oil correlations utilize all available data, placing the greatest emphasis on those data that are least likely to have been affected by non-genetic transformation processes, such as biodegradation, cracking, phase separation, and migration. Bulk properties such as API gravity and sulfur content are therefore of less value than molecular and isotopic parameters (Waples & Curiale, 1999).
The most-valuable correlation data are usually biomarkers, derived from GC-MS analysis. Gas chromatography and carbon isotopes can also be useful.
The thermal history of an oil affects its gross properties in predictable ways: API gravity, saturated hydrocarbon content, and saturate/aromatic ratio increase, while sulfur content, viscosity, wax content, and pour point decrease. However, these parameters are often affected by other factors, such as variations in source-rock facies, biodegradation, phase changes in the reservoir, and migration, and thus cannot always be used quantitatively to evaluate maturity levels of oils. Gas chromatography is slightly more sensitive, but also cannot provide highly quantitative answers. The most reliable way of quantitatively evaluating the maturity of most oils is biomarkers, which are obtained from GC-MS analysis. For extremely mature oils, where the standard biomarkers have been destroyed by high temperatures, diamondoids provide a useful alternative.
Unfortunately, some of the most-commonly used biomarker data are of limited value for oils. The mixture of R and S epimers of extended hopanes normally reaches equilibrium long before oil generation occurs, and thus is not useful at all. Similarly, the mixture of R and S epimers of steranes reaches equilibrium prior to peak generation, and thus often cannot be used to determine precise oil maturity. Aromatic indicators such as the Methylphenanthrene Index (MPI) are valid only for oils that are generated from Type III kerogen, a serious limitation that is often overlooked by interpreters (Matthias Radke, personal communication).
We believe that the most-useful indicators of oil maturity are the Tm/Ts ratio (also expressed as Ts/Tm or Ts/(Tm+Ts)), the sterane/triterpane (or sterane/hopane) ratio, and the absolute concentration of total hopanes (or simply of the C30 hopane) in the sample. None of these ratios is currently very popular, mainly because the values vary from one organofacies (or oil type) to another, and they therefore must be calibrated for each system. Nevertheless, we have had very good success employing these ratios – calibration is generally not difficult, and the results are very consistent and cover a very wide range of oil maturity.
The plot below shows Ts/Tm covarying with the absolute concentration of C30 hopane in a single family of oils. With appropriate calibration data, all these maturity parameters can be linked, at least approximately, to Transformation Ratios in source rocks, and to vitrinite reflectance values.
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