Abstract: Depositional environment and source potential of the
different organic-rich levels of Devonian age (up to 990m thick) from
the onshore EC-1 well (Southern Tunisia) were investigated based on
the analysis of more than 130 cutting samples by different
geochemical techniques (Rock-Eval pyrolysis, GC-MS). The
obtained results including Rock Eval Pyrolysis data and biomarker
distribution (terpanes, steranes and aromatics) have been used to
describe the depositional environment and to assess the thermal
maturity of the Devonian organic matter. These results show that the
Emsian deposits exhibit poor to fair TOC contents. The associated
organic matter is composed of mixed kerogen (type II/III), as
indicated by the predominance of C29 steranes over C27 and C28
homologous, that was deposited in a slightly reduced environment
favoring organic matter preservation. Thermal maturity assessed from
Tmax, TNR and MPI-1 values shows a mature stage of organic
matter. The Middle Devonian (Eifelian) shales are rich in type II
organic matter that was deposited in an open marine depositional
environment. The TOC values are high and vary between 2 and 7%
indicating good to excellent source rock. The relatively high HI
values (reaching 547 mg HC/g TOC) and the low values of t19/t23
tricyclic terpane ratio (< 0.2) confirm the marine origin of the organic
matter (type II). During the Upper Devonian, the organic matter was
deposited under variable redox conditions, oxic to suboxic which is
clearly indicated by the low C35/C34 hopanes ratio, immature to
marginally mature with the vitrinite reflectance ranging from 0.5 to
0.7 Ro and Tmax value of 426°C-436 °C and the TOC values range
between 0.8% to 4%.
Abstract: Natural hydrocarbon seepage has helped petroleum
exploration as a direct indicator of gas and/or oil subsurface
accumulations. Surface macro-seeps are generally an indication of a
fault in an active Petroleum Seepage System belonging to a Total
Petroleum System. This paper describes a case study in which
multiple analytical techniques were used to identify and characterize
trace petroleum-related hydrocarbons and other volatile organic
compounds in groundwater samples collected from Sousse aquifer
(Central Tunisia). The analytical techniques used for analyses of
water samples included gas chromatography-mass spectrometry (GCMS),
capillary GC with flame-ionization detection, Compound
Specific Isotope Analysis, Rock Eval Pyrolysis. The objective of the
study was to confirm the presence of gasoline and other petroleum
products or other volatile organic pollutants in those samples in order
to assess the respective implication of each of the potentially
responsible parties to the contamination of the aquifer. In addition,
the degree of contamination at different depths in the aquifer was also
of interest. The oil and gas seeps have been investigated using
biomarker and stable carbon isotope analyses to perform oil-oil and
oil-source rock correlations. The seepage gases are characterized by
high CH4 content, very low δ13CCH4 values (-71,9 ‰) and high
C1/C1–5 ratios (0.95–1.0), light deuterium–hydrogen isotope ratios (-
198 ‰) and light δ13CC2 and δ13CCO2 values (-23,8‰ and-23,8‰
respectively) indicating a thermogenic origin with the contribution of
the biogenic gas. An organic geochemistry study was carried out on
the more ten oil seep samples. This study includes light hydrocarbon
and biomarkers analyses (hopanes, steranes, n-alkanes, acyclic
isoprenoids, and aromatic steroids) using GC and GC-MS. The
studied samples show at least two distinct families, suggesting two
different types of crude oil origins: the first oil seeps appears to be
highly mature, showing evidence of chemical and/or biological
degradation and was derived from a clay-rich source rock deposited
in suboxic conditions. It has been sourced mainly by the lower
Fahdene (Albian) source rocks. The second oil seeps was derived
from a carbonate-rich source rock deposited in anoxic conditions,
well correlated with the Bahloul (Cenomanian-Turonian) source rock.