The distinction between conventional and unconventional hydrocarbon accumulations depends on whether oil or gas are hosted within a well-defined trap and whether they can be produced economically by wells. The unconventional oil and gas... more
The distinction between conventional and unconventional hydrocarbon accumulations depends on whether oil or gas are hosted within a well-defined trap and whether they can be produced economically by wells. The unconventional oil and gas resources cannot be extracted economically by using conventional methods and technologies, while the conventional accumulations refer to technically and economically recoverable hydrocarbons. The unconventional accumulations are characterized by large resources but poor reservoir properties. Conventional hydrocarbons only account for less than 20% of the world’s fossil fuel resources, whereas unconventional hydrocarbons account for at least 80%. On the Romanian territory, 10 petroleum basins with different hydrocarbon richness have been identified: Moesian Platform, Transylvanian Basin, Eastern part of Pannonian Basin, Eastern Carpathians Flysch, Moldavian Platform, Carpathian Foredeep, Schythian Platform, Maramures Basin, North-Dobrogean Promontory and the Romanian shelf of the Black Sea. In these basins more than 18 petroleum systems have been identified. Almost all these petroleum basins contain unconventional hydrocarbon resources like shale gas, shale oil, heavy oil, tar sands, tight sands gas, gas hydrates and coal bed methane (CBM).
X-ray absorption near-edge structure (XANES) methodology has been employed to quantify the different sulfur structures present in three Type I and three Type II kerogens. Kerogens from the Green River (3), Bakken (1), Woodford (1), and... more
X-ray absorption near-edge structure (XANES) methodology has been employed to quantify the different sulfur structures present in three Type I and three Type II kerogens. Kerogens from the Green River (3), Bakken (1), Woodford (1), and Indiana limestone (1) formations were studied. Both aliphatic (sulfide) and aromatic (thiophene) forms of sulfur exist in all these kerogen samples. Except for Woodford, all of the kerogens contain oxidized functional groups. Sulfur in Types I and II kerogens mimics the carbon chemistry in that the sulfur structures are more aromatic in Type II than in Type I. It was impossible to differentiate elemental sulfur from pyrite in these samples by using K-edge XANES.
Genetic relations between the abyssal evolution of the Earth and the formation of near-surface oil and gas fields represent one of the main geological problems. Solution of this problem is impossible on the basis of the widely accepted... more
Genetic relations between the abyssal evolution of the Earth and the formation of near-surface oil and gas fields represent one of the main geological problems. Solution of this problem is impossible on the basis of the widely accepted hypotheses of formation of the Earth and planets from "a cold cosmic material," which are considered in (Kholodov, 2006), because they give no answer to the main question of formation mechanism for the Earth's initially liquid huge nickel-iron core, which is generating hydrogen fluid flows during the past 4.6 Ga and providing its endogenic development. The answer to this question can be given only based on understanding complex genetic relationships between giant planets, their satellites, and planets of the Earth group (Marakushev, 1999, 2005). Among these planets, the Earth is characterized by a remarkable duration of its endogenic activity that was lost by other planets of its group, along with magnetic fields, due to their complete consolidation.
Oil and gas production in Alaska has historically been limited to the northern and southern margins of the state, primarily in the North Slope and Cook Inlet, but recent drilling, seismic, and exploration data in Interior Alaska suggests... more
Oil and gas production in Alaska has historically been limited to the northern and southern margins of the state, primarily in the North Slope and Cook Inlet, but recent drilling, seismic, and exploration data in Interior Alaska suggests potential for large oil and gas fields in rift basins near Nenana and Yukon Flats.
Carbonaceous material (CM) is thought to be a key reductant contributing to the formation of large Au deposits, but there has been much speculation about its source, molecular composition and reactivity. The first successful analytical... more
Carbonaceous material (CM) is thought to be a key reductant contributing to the formation of large Au deposits, but there has been much speculation about its source, molecular composition and reactivity. The first successful analytical retrieval of organic compounds from a thermally over-mature (> 550 °C) Paleoproterozoic Cosmo-Howley Orogenic Au deposit was recently achieved by Robert et al. (2016). Here, we have evaluated the nature of the CM associated with this high temperature Au mineralisation via an integrated analytical approach which combined high-resolution in situ laser Raman spectroscopy, micro to nano-scale imaging (e.g., EELS, HAADF-STEM, and HRTEM) and molecular and isotopic geochemistry. We identified two distinct CM types: CM ker – an ubiquitous highly graphitic kerogen typical of high-grade metamorphic conditions formed by regional meta-morphism; and CM fd – small sub-microscopic inclusion-like nodules of highly disordered carbon rich in poly-cyclic aromatic hydrocarbons (PAHs), coincident within the Au-bearing sulfide minerals in hydrothermal vein regions. The paragenetic emplacement and molecular characteristics of CM fd suggests a formation by metaso-matic processes and introduction by a hydrothermal fluid which might also have co-transported Au. CM ker and CM fd gave different Raman spectra indicative of their contrasting origin and structural response to regional and contact metamorphic history and subsequent metasomatism of the Cosmo-Howley deposit. Raman signals indicated CM ker had a graphitic like structure whereas CM fd comprised high concentrations or clusters of PAHs. The broad range of Raman spectra detected here (and by others in similar studies) was likely due to the mixed signals of these two types of CM. The δ13C values of PAH products released via the HyPy treatment of the parent and sequentially demineralised kerogen fractions were measured to be in the range of −20 to −30‰, indicative of an organic biopolymeric origin. The δ13C values of PAHs products decreased with demineralisation, con-comitant with an increase in their concentrations and affinity to the sulfide-minerals (and associated CM fd) suggesting a close relationship. The localised (within 20 mm) co-occurrence of different CM types and apparent abundance correlation of CM fd with Au and sulfides suggests Au mineralisation might be supported by specific CM types, and these relationships should be evaluated further including on a wider Au deposit scale.
The studied borehole is located near the city of Fălticeni, in the western part of the Moldavian Platform. The lithology consists of sands/sandstone, claystone and shale. In the present study, for the interpretation of the palynofacies,... more
The studied borehole is located near the city of Fălticeni, in the western part of the Moldavian Platform. The lithology consists of sands/sandstone, claystone and shale. In the present study, for the interpretation of the palynofacies, 16 samples from the Baia borehole, collected at depths between 290 and 1050 m, have been analyzed. For the analysis of the Total Organic Carbon (TOC), 10 samples were prepared and analyzed. For most of the samples, the results for the hydrocarbon potential vary from fair to good. In order to establish the type of kerogen, 4 samples were studied and the H/C and O/C ratios were calculated and plotted in a van Krevelen diagram. The type of kerogen resulted is III. The samples analyzed for the study of the palynofacies mostly belong to field III, according to the Tyson (1995) diagram. This field is characterized by a predominance of phytoclasts, which indicate a fluvial-deltaic source where the palynomorphs are fairly preserved. Amorphous Organic Matter (AOM) is present in low percentage. The color of the sporomorphs in fluorescent light is yellow, which corresponds to a 580 nm wavelength. The same color was noticed for the AOM studied in fluorescent light.
The hydrocarbon potential, organic source input, and paleodepositional environment of subsurface sediments from EE-1 well, offshore Eastern Dahomey Basin, were assessed using Rock-Eval pyrolysis and biomarker geochemistry. The total... more
The hydrocarbon potential, organic source input, and paleodepositional environment of subsurface sediments from EE-1 well, offshore Eastern Dahomey Basin, were assessed using Rock-Eval pyrolysis and biomarker geochemistry. The total organic carbon (TOC) and soluble organic matter (SOM) in the sediments ranged from 0.96wt% to 8.92wt% and 676.12 ppm to 2883.85 ppm, respectively, indicating adequate to excellent organic richness. The pseudo-Van Krevelen plot classified the sediments as types II and III kerogen, which have the potential to generate both oil and gas. The Tmax and production index (PI) ranged from 422°C to 431°C (average, 426°C) and 0.03 to 0.24, respectively, suggesting low thermal maturity. The presence of C27–C29 steranes, oleanane, and hopane/sterane ratio (1.53/16.11), indicated organic matter from mixed sources with more terrigenous input. Cross plots of Pr/nC17 against Ph/nC18, C35/C31 – C35 homohopane index (0.05 – 0.17) and other related biomarker ratios such as ...
On the basis of an inorganic concept of the petroleum origin, the phase relationships of crystalline kerogens of black shales and liquid oil at the physicochemical conditions of a typical geobarotherm on the Texas Gulf Coast are... more
On the basis of an inorganic concept of the petroleum origin, the phase relationships of crystalline kerogens of black shales and liquid oil at the physicochemical conditions of a typical geobarotherm on the Texas Gulf Coast are considered. At the conditions of the carbon dioxide (CO2) high fluid pressure, the process of oil transformation into kerogens of varying degrees of "maturity" (retrograde metamorphism) takes place with decreasing temperature and hydrogen pressure. Kerogen generation in black shale rocks occurs by the sequential transition through metastable equilibria of liquid oil and crystalline kerogens (phase "freezing" of oil). The upward migration of hydrocarbons (HC) of oil fluids, clearly recorded in the processes of oil deposit replenishment in oil fields, shifts the oil ↔ kerogen equilibrium towards the formation of kerogen. In addition, with decreasing of the hydrogen chemical potential as a result of the process of hightemperature carboxylation and low-temperature hydration of oil hydrocarbons, the "mature" and "immature" kerogens are formed, respectively. The phase relationships of crystalline black shale kerogens and liquid oil under hypothetical conditions of high fluid pressure of the HC generated in the regime of geodynamic compression of silicate shells of the Earth in the result of the deep alkaline magmatism development. It is substantiated that a falling of hydrogen pressure in rising HC fluids will lead to the transformation of fluid hydrocarbons into liquid oil, and as the HC fluids rise to the surface, the HC ↔oil ↔ kerogen equilibrium will shift towards the formation of oil and kerogen. It is round that both in the geodynamic regime of compression and in the regime of expansion of the mantle and crust, carboxylation and hydration are the main geochemical pathways for the transformation of oil hydrocarbons into kerogen and, therefore, the most powerful geological mechanism for the black shale formations.
A methodology to determine the chemistry and kinetics of the multiple reactions during geological maturation was developed, with a special emphasis on the representation of diagenesis and oil formation processes. The methodology combines... more
A methodology to determine the chemistry and kinetics of the multiple reactions during geological maturation was developed, with a special emphasis on the representation of diagenesis and oil formation processes. The methodology combines a unique macromolecular and kinetic model for hydrocarbon pyrolysis, the FG-DVC (functional group devolatilization, vaporization, cross-linking) model, with a method of analysis based on thermogravimetric analysis with Fourier transform infrared spectroscopy (TG-FTIR). TG-FTIR pyrolysis data from several natural maturation series of coals and kerogens were measured, systematic trends with the degree of maturation were identified, and empirical processes and reaction kinetics during maturation necessary to induce these trends were estimated. This approach eliminates potential inaccuracies when extrapolating kinetic parameters obtained from laboratory experiments to geological conditions. The FG-DVC pyrolysis model was modified to include these maturation processes, with aqueous chemistry providing a guide for such modifications. The resulting FG-DVC maturation model was then used to predict the maturation of several immature samples through the well-known time/temperature history of the basin. The FG-DVC pyrolysis model was subsequently used to predict the open-system pyrolysis decomposition of the predicted maturation residues, and the predictions were compared to TG-FTIR data of the corresponding naturally matured samples. For most of the series investigated, the model gave good predictions of the variations in oxygenated gas precursors, tar Tmax, and extractable yield with maturation. Kinetics derived from open-system pyrolysis for bridge breaking were found to be applicable during maturation. However, faster kinetics were necessary to describe the removal of oxygenated gas precursors. In addition, the removal of methane and tar was found to be too slow during maturation when using open-system pyrolysis kinetics. Artificial maturation experiments using confined pyrolysis were also performed for comparison. While the evolution rates, during subsequent pyrolysis of the maturation residues, of oxygenated gas species are different from those obtained from samples naturally matured, the yields compare favorably with model predictions. The trends for pyrolysis tar and methane from artificially matured samples are similar to those of natural samples but suggest different kinetics.