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This study reveals the hydrocarbon production potential and thermal maturity of Çilhoroz coals, which is the most important local coal field around Erzincan in the Eastern Anatolia Region. This area is one of the best examples of the continental collision zone in the world and is located in a north-south convergent collision zone between the Eurasian and Arabian Plates. The average thickness of the coal seam is about 4 m and these coals are currently mined by open pit mining methods. Coal is predominated by combined xylitic/attrital lithotypes and by huminite macerals with inertinite and minor liptinite macerals. The content of mineral matter is variable but generally low, it consists mostly of quartz, calcite, clay minerals, and pyrite. Although the Rock-Eval pyrolysis data show that the investigated coal bearing unit is represented by a significant hydrocarbon (oil and gas) potential, hydrocarbon species did not develop due to low maturation. [ABSTRACT FROM AUTHOR]

Petroleum hydrocarbons are one of the most well-known environmental pollutants not only for plants, and animals but also for humans because of their carcinogenic mutagenic, toxic, and teratogenic effects. Hence, various remediation technologies have been used to overcome these environmental pollutants. Among them, bioremediation is novel promising sustainable approach for treating petroleum and petroleum derivative raw material deleterious components with their effective, low-cost eco-friendly features. In this perspective, the evaluation of soil samples was collected from areas containing petroleum and petroleum derivatives from Kazanlı and Karaduvar refinery regions in Mersin-Turkey. Hence, potential hydrocarbon and petroleum degrading bacteria were identified and characterized by the MALDI-TOF MS method as well as biochemical, physiological, and morphological tests. According to the MALDI-TOF MS analysis; members of Bacillus, Stenotrophomonas, Enterobacter, Pseudomonas, Cupriavidus, Acinetobacter, and Escherichia were successfully identified as hydrocarbon and petroleum degrading bacteria. [ABSTRACT FROM AUTHOR]

The study examines the energy resources specific to the Eastern Mediterranean region in the context of regional energy policies. Although natural gas is already an important energy source, its importance is increasing day by day in our world. This situation showed itself with new regional developments and was felt especially in the Eastern Mediterranean region. With the recent developments, the importance of natural gas has also increased for Turkey. In this context, the reserve status of natural gas in the world as an energy source has been considered, and it has also been interpreted together with data such as its production, import and export in the world. Then, the Eastern Mediterranean issue was examined and in this context, historical developments that have taken place so far have been discussed. In the light of historical developments, energy competition in the Eastern Mediterranean region has also been analyzed. In particular, the interest and needs of the countries in the region in this field were also evaluated. However, also assessed other chronic particularly concerned with reflections on the problems of energy competition between Turkey and Greece. Finally, implications were made about how the potential gas in the region could be used. The proper utilization of this potential will protect the environment of peace that will increase regional prosperity and stability. [ABSTRACT FROM AUTHOR]

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In the work presented here, core and cutting samples from a single well were studied with the aim of understanding the diagenesis and reservoir properties of the Kömürlü and Penek Formation sandstones in the Aşkale sub-basin in East Anatolia. Based on petrological and hydrocarbon saturation analyses [attenuated total reflectance-Fourier-transform infrared spectroscopy] of the samples, we discuss the relationships between diagenetic alterations and reservoir quality. The diagenetic alterations include quartz, feldspar overgrowth, calcite, smectite, chlorite, mixed-layer illite–smectite, mixed-layer chlorite–smectite, illite, kaolinite, and pyrite. After the diagenetic mineral phases formed, secondary porosity formed via dissolution of late carbonate cement in these sandstones. Diagenesis in the Kömürlü and Penek Formation sandstones commonly destroyed much of the original intergranular porosity, dissolved grains, and produced clay-filled pores. The pore throats typically range in size from 1 to 5 µm and represent only a small portion of the total porosity. This study is the first attempt to make petrophysical data available from the well logs of the reservoir sandstones (Kömürlü and Penek Formations) in the Aşkale sub-basin of the East Anatolia Basin. The results of this study will clarify the characterization of the reservoir sandstones. [ABSTRACT FROM AUTHOR]

Sedimentological and petrographic studies of the Haymana Formation sandstones identify a submarine fan in the Haymana Basin. This study is confined to outcrop samples from the submarine-fan sandstones (the L1, L2, and L3 sections) and focuses on documentation of the petrographic characteristics of and depositional controls on reservoir properties of the Haymana Formation sandstones. Analysis of the lithology, texture, sedimentary structure, and petrography of the outcrop samples allows separation of the Haymana Formation sandstones into three distinct lithofacies, A, B, and C. Lithofacies A sandstones exhibit medium-coarse grain sizes (0.4–0.6 mm), moderate-good sorting, and subrounded grains. Lithofacies B sandstones exhibit fine grain sizes (0.2 mm), moderate sorting, and subrounded-subangular grains. Lithofacies C sandstones exhibit very fine grain sizes (0.112 mm) and nonreservoir facies. The main aim of this study is to document the diagenetic history and reservoir quality of the Haymana Formation sandstones. Lithofacies A has the best permeability, ranging from 80 to 120 mD, which can be related to the large grain size, the presence of cross-bedding, small amount of authigenic clays or cements in the pore throats, and enlarged pore apertures. In contrast, Lithofacies B sandstones contain variable yet small pore and pore-throat sizes, which are affected by abundant pore-filling authigenic clays, small grain sizes, and no dissolution. The permeability of the Lithofacies B sandstone ranges from 16 to 35 mD, which is lower than that of the Lithofacies A sandstone. Additionally, the Lithofacies B sandstones have small median pore-throat sizes (mean = 1.52 μm) and low porosities (average 4–6%), and the Lithofacies A sandstones have large pore-throat sizes (mean = 2.06–3 μm) and high porosities (average 20–25%), with most pore throats (50% or more) ranging between 1 and 4 μm. According to these data, the Lithofacies A sandstones show good reservoir characterisation. To date, significant hydrocarbon deposits have not been discovered in the Haymana Formation sandstones, although intensive exploratory work towards this end has been carried out in the Haymana Basin. According to this study, the proximal sandstones of the submarine-fan complex of the Haymana Formation may contain high-potential reservoirs in the Haymana Basin. In the basin, hydrocarbon is sourced from deep zones and may be capped by the proximal part of the Haymana Formation sandstones. According to this study, the Lithofacies B sandstones of the Haymana Formation are not suitable as diagenetic traps for hydrocarbon exploration in the Haymana Basin. However, the Lithofacies A sandstones may be expected to have the highest exploration success. [ABSTRACT FROM AUTHOR]

Abstract Hydrocarbon micro and macro seeps alter chemical and mineral composition of the Earth's surface, providing prospects for detection with remote sensing tools. There have been several studies focusing on mapping these anomalies by utilizing ever evolving multispectral and hyperspectral imaging instruments, which has proven their capacity for mapping both hydrocarbons and hydrocarbon-induced alterations so far. These studies broadly comprise of methods like calculating band ratios, spectral angle mapping, spectral feature fitting, and principal component analysis as detection techniques. However, there is a lack of concentration on advanced signature based detection algorithms and unmixing methods for mapping surface manifestations of hydrocarbon microseeps. Signature based detection algorithms utilize target spectra to correlate with each pixel's spectrum in order to allocate possible target locations. Unmixing methods, on the other hand, require no input spectra beforehand, aiming to resolve each pixel's spectral constituents and their corresponding abundance fractions. In this paper, the potential of all these methods in mapping microseepage related anomalies are evaluated by implementing and comparing them for Gemrik Anticline, one of the prospective hydrocarbon exploration fields in Turkey. Hence, it provides a complete knowledge on determination surface manifestations of hydrocarbon microseeps with the help of well known supervised target detection algorithms and hyperspectral unmixing algorithms. The study area is located in the Southeastern Anatolia, between the cities of Adıyaman and Şanlıurfa. The spectral signatures were collected with Analytical Spectral Devices Inc. (ASD) spectrometer during the field studies conducted by Avcıoğlu (2010), to be utilized as an input to the signature based detection algorithms as well as a reference to select the related abundance map among the outputs of unmixing methods. Advanced Space Borne Thermal Emission and Radiometer (ASTER) image of the study region, with an atmospheric correction before running the algorithms, is selected for the applications. Among the applied algorithms, Simplex Identification via Split Augmented Lagrangian (SISAL) is selected as a base of comparison, as it possess minimum calculated error metrics in the experiments. Another unmixing method, the Minimum Volume Simplex Algorithm (MVSA), and signature-based techniques, Desired Target Detection and Classification Algorithm (DTDCA) & Spectral Matched Filter (SMF) follow the success of the SISAL, respectively. The Crosta technique, which is performed as a conventional approach for experimental comparisons, has also shown its capability, succeeding these algorithms. The study provides an overall assessment for methodologies to be used for hydrocarbon microseepage mapping, which also serves guidance for further exploration studies in the region. The potential of ASTER data for hydrocarbon-induced alterations is also emphasized as a cost effective tool for the future applications. [ABSTRACT FROM AUTHOR]

The Neogene coals of the Hotamış Formation in the Konya-Karapınar basin were examined, and the organic matter type, thermal maturity, paleodepositional environment, and Rock-Eval pyrolysis characteristic of coal samples obtained from boreholes. The total organic carbon (TOC) values of coal vary between 15.2 wt% and 47.0 wt% and the yield of extractable organic matter (EOM) values varies between 0.5% and 1.0% indicating a limited hydrocarbon production potential. Bitumen index (BI) and Quality index (QI) values were calculated for coal samples and vary from 1 to 13 mg HC/g TOC and from 75 to 260 mg HC/g TOC, respectively. Due to BI and QI values, coal samples have limited gas generation potential. The type of organic matter was determined as Type III kerogen according to Rock-Eval data. The coal samples have Tmax values between 414 and 443 °C, and huminite reflectance values with 0.20%–0.41% Ro indicating that they are in the immature-early mature stage. This is supported by biomarker maturity parameters 20S/(20S + 20R) (C 29) sterane (0–0.59), ββ/(αα + ββ) (C 29) sterane (0–0.58), MPI-1 (0.18, 0.31) and MPI-1* (0.21, 0.37). The relative abundance of C 27 –C 28 –C 29 normal steranes and aromatic steroids and the abundance of partially low carbon number tricyclic terpanes of the Konya-Karapınar coals showed that the organic matter consisted of terrestrial higher plants with a small contribution of algae and microorganisms. Homohopane distributions, V/(V + Ni), V/Sc ratios show that organic matter accumulated in an environment that varies between oxic-anoxic conditions and that medium-high gammacerane index, C 27 –C 28 –C 29 sterane distributions, and low DBT/P ratios are compatible with the weak brackish water-fresh water depositional environment of organic matter. [Display omitted] • Konya-Karapınar coals were investigated using biomarker data. • The coals investigated were excellent in terms of hydrocarbon production potential and were of gas origin. • Aliphatic and aromatic biomarkers showed depositional environment characteristics and maturity level of the lignite coal. • Trace element ratios gave information about the redox conditions, paleoclimate, and salinity of the depositional environment. [ABSTRACT FROM AUTHOR]

Abstract: This paper reports microfacies, diagenesis and reservoir properties of the Lower–Middle Miocene Karaisalı Formation in the Adana Basin, southern Turkey. The Karaisalı Formation reflects the continuous deposition of shallow-shelf carbonates; periodic rises in sea level led to episodes of deeper water sedimentation. The formation was studied using outcrop samples from the Karaisalı region. Karaisalı Formation carbonates are up to 500 m thick. Abundant bioclasts include corals, red algae, bryozoans and benthonic and planktonic foraminifera. The best reservoir conditions in the Karaisalı Formation occur in grain-supported facies such as Foraminiferal–Algal packstones. Secondary vuggy and moldic porosity, which are common in the Foraminiferal/Algal Packstones, resulted from micritic cement and the dissolution of skeletal grains during early diagenesis. Foraminiferal/Algal Packstones are characterised by porosities of >20% and by permeabilities between 7 mD and 18 mD. Other carbonate facies, such as planktonic wackestones and coralgal boundstones have poorer reservoir characteristics. Most pore throats (50% or more) range between 1 and 2 µm, and only a small percentage of pore throats are less than 1 µ. These results indicate that the Karaisalı limestones have intermediate – good reservoir characteristics. The carbonates were affected by a range of diagenetic processes, including grain dissolution which led to the formation of secondary porosity reduced by calcite cementation. The wackestone and boundstone facies of the Karaisalı limestones are not suitable targets for hydrocarbon exploration in the Adana Basin. However, the Foraminiferal/Algal packestone facies may have a higher exploration success. [Copyright &y& Elsevier]

Units in the Thrace basin with respect to petroleum geology can be divided into two parts: pre-Tertiary and Tertiary deposits. Pre-Tertiary units are generally represented with ophiolites, green schists, and magmatic rocks comprising the basement and upper Cretaceous sediments. The Oligocene Osmancık formation, the upper Eocene-lower Oligocene Mezardere formation, the Eocene Hamitabat, Soğucak, and Ceylan formations encountered in the Minnetler-1A and Karakavak-1 wells drilled in the Thrace basin, are composed of shale, limestone, and sandstone. On the basis of organic geochemical and organic petrographic observations in the Minnetler-1A and Karakavak-1 wells, organic components of the Eocene-Oligocene formations are generally terrestrial organic materials (Type II and Type III kerogens). In the Minnetler-1A and Karakavak-1 wells, organic material contents of units are between 0.08 and 2.48 wt%. On the basis of these values, the Eocene-Oligocene units in both wells show weak to good source rock potentials. According to maturity parameters, Eocene-Oligocene units in the Minnetler-1A and Karakavak-1 wells are at immature and mature oil zone. [ABSTRACT FROM AUTHOR]

Hydrocarbon potential of oil shale samples from the Gökçesu basin in Bolu, Turkey, was evaluated on the basis of organic geochemical, organic petrographic, gas chromatography, and thin-layer chromatography techniques. Organic materials were found to be oil-producing type (Type I and II kerogen). Thermal maturities, that indicate diagenetic and early mature oil formation stage, were determined with pyrolysis (Tmax), production index (PI), and spore color index (SCI) analyses. The amount of organic material ranging between 0.21 and 15.89% reveals that the unit has variable source rock potentials from weak to perfect. The productivity of the basin was probably high and organic matter preservation was enhanced by a stratified water column. As the basin began to fill with sediment and become shallower, TOC and HI values declined, as the basin water was better oxygenated and preservation conditions declined. On the basis of geologic data, organic geochemical analyses and organic petrographic studies, organic facies of Eocene shales is of AB and B types. [ABSTRACT FROM AUTHOR]

Ductile lithic grain, secondary porosity, temperature, and overpressure control porosity and permeability in the Mio-Pliocene and Upper Oligocene sandstones of the Aşkale sub-basin in East Anatolia. Ductile lithic grains account for between approximately 60–90% of the original sand grain population. There is a pronounced loss of porosity with increasing bruial depth in this sub-basin. At depths of less than 3000 m, this is due solely to ductile-lithic grain compaction where the rate of porosity loss of with depth increases with increasing ductile-lithic grain content. But at depths greater than 3000 m, the steep porosity increases with depth due to secondary solution activities and overpressure in the Aşkale sub-basin in East Anatolia. Secondary porosity is a common diagenetic feature in the more deeply buried (> 3000 m) sediments in the Aşkale sub-basin. The secondary porosity arises principally from dissolution of feldspar, to a lesser extent, of the quartz (approximately 10–30%). Overpressure is due to tectonic stress. Reservoir quality is thus controlled by secondary solution activities, overpressure, temperature (geothermal gradient) and depth of burial in the Aşkale sub-basin in East Anatolia Basin. [ABSTRACT FROM AUTHOR]

Abstract: Units of Paleozoic, Mesozoic and Cenozoic age are exposed in the study area which extends along the Sakarya River by the Sarýcakaya town of Eskiþehir at west and Nallýhan district of Ankara at East. Paleozoic is represented with metamorphites consisting of glaucophane schist, muscovite schist and marble alternations and granites cutting them. The Mesozoic composing of Jurassic–Cretaceous Soğukçam limestones at the northern part of the area is in tectonic contact with other units. The Tertiary is characterized by the Paleocene–Eocene Kızılçay Group which consists of the Beyköy, Çamalan and Laçin Formations. The Çamalan Formation is composed of sandstone, limestone, oil shale and locally coal bands. In the area, as a result of intense tectonic activity by the late Eocene, sedimentary sequence that compacted within the Paleozoic metamorphic rocks were folded and fractured. The Paleocene–Eocene shales have adequate organic material content to form potential source rocks. In order to determine hydrocarbon potential of the unit, various organic geochemical analysis techniques were performed. According to pyrolysis results (TOC, S1 and S2), the Paleocene–Eocene shales are perfect source rocks for oil. On the basis of Rock-Eval pyrolysis analyses, kerogens are Type I and Type II kerogens. Spore Color Index and T max evaluations indicate that maturity of the unit is between diagenesis and early mature oil zone and at the beginning of the oil-producing stage. Organic facies of the Paleocene–Eocene shales are A, AB and B. [Copyright &y& Elsevier]