Petroleum geology

The Garzan Formation is a deepening upward marine carbonate including successions ranging from subtidal to open marine facies deposited in the Maastrichtian. The Garzan Formation is composed of five microfacies types; Miliolid Wackestone (subtidal), Orbitoid Miliolid Wackestone, Rudist Wackestone (backshoal to shoal), Rotalid Miliolid Wackestone (shoal to foreshoal) and Pelagic Foraminiferal Mudstone (foreshoal to open marine). These five microfacies are stacked in different combinations consisting of five types of depositional cycles. The type A and D cycles the building blocks of transgressive systems tract (retrogradational), whereas type B and C cycles are deposited during highstand systems tract (aggradational). The type E cycle is progradational and also corresponds to the highstand systems tract deposits. The maximum flooding surface is usually located within the type D cycle towards the top of the formation. vi Generally, the base of the Garzan Formation deposition starts wi...

Programmed pyrolysis of mudstone provides a rapid and effective technique to recognize nearshore environments of deposition in the subsurface. Ninety-three mudstone samples from four downdip Sparta Formation wells in south-central Louisiana were analyzed using a Rock-Eval pyrolysis analyzer with TOC module. Detailed conventional core analysis demonstrates that the Sparta Formation in the study area represents a prograding barrier island complex consisting of reservoir-quality shoreface, storm washover, and tidal-inlet sandstone (Lemoine et al., 1988). Sandstone units overlie open-marine mudstone and are capped by lagoonal mudstone. Mudstone of both fades is characteristically dark brown to black, laminated and organic rich. However, pyrolysis results reveal geochemical contrasts which can be used to distinguish between the marine mudstone facies and the lagoonal mudstone facies. Total Organic Carbon (TOC) (Fig. ) and Hydrogen Index (with Oxygen Index, Fig. ) were found

Programmed pyrolysis of mudstone provides a rapid and effective technique to recognize nearshore environments of deposition in the subsurface. Ninety-three mudstone samples from four downdip Sparta Formation wells in south-central Louisiana were analyzed using a Rock-Eval pyrolysis analyzer with TOC module. Detailed conventional core analysis demonstrates that the Sparta Formation in the study area represents a prograding barrier island complex consisting of reservoir-quality shoreface, storm washover, and tidal-inlet sandstone (Lemoine et al., 1988). Sandstone units overlie open-marine mudstone and are capped by lagoonal mudstone. Mudstone of both fades is characteristically dark brown to black, laminated and organic rich. However, pyrolysis results reveal geochemical contrasts which can be used to distinguish between the marine mudstone facies and the lagoonal mudstone facies. Total Organic Carbon (TOC) (Fig. ) and Hydrogen Index (with Oxygen Index, Fig. ) were found

The structure of the south Taiwan fold-and-thrust belt (FTB) comprises a roughly N-S striking, west-verging imbricate thrust system that has been developing since the Late Miocene. Here, we present the results of new surface geological mapping, serial balanced cross sections, long sections, and a map of the basal thrust that are combined with published borehole data and a 3D P-wave tomography model to constrain the structure at depth. The stratigraphy of the area comprises Eocene syn-rift sediments that are unconformably overlain by Oligocene through Middle Miocene shallow water post-rift sediments. These are unconformably overlain by Late Miocene through Holocene-age syn-orogenic sediments. We define the basement to these as the Mesozoic pre-rift rocks of the Eurasian margin, and assign it a P-wave velocity of > 5.2 km/s in the velocity model. The syn-orogenic sediments thicken and get progressively involved in the thrust sheets toward the south. The south Taiwan FTB can be divided into several thrust sheets. In the northern part of the map area, the structural grain is roughly N-S striking, changing southward to become NE-SW oriented. The westernmost thrust sheets form broad, open synclines cored by Pliocene to Holocene sediments, and tight hanging wall anticlines formed by Miocene rocks. Along its eastern flank, a narrow, complexly folded anticlinorium is developed in Miocene rocks. Restoration of the cross-sections indicates about 15 to 17 km of shortening. The basal thrust deepens from the surface towards the E and SE in a staircase trajectory, with narrow ramps and wide flats, reaching up to 8 km depth in the east before ramping down into the basement. The basal thrust has two pronounced, NE-striking oblique ramps that coincide with sigmoidal changes in shape of structures in the hanging wall. These correlate with a SW-NE trending increase in the P-wave velocity that is interpreted to image a basement high. We interpret this basement high to be an inherited extensional structure of the margin, and that faults associated with it are being reactivated, causing the changes in strike of the basal thrust, as well as in the surface trace of thrust and fold axes.

Abstract: Experimental results obtained during oil displacement by water within a cell are presented. This cell, built with acrylic (an oil wet material) simulates a natural vuggy fractured porous medium. Based on the experimental results, a theoretical model was ...

The Ekenkpon bivalves were used to deduce the environment of deposition in the Calabar Flank. During the Cenomanian-Turonian times, regionally based marine transgression and regression occurred along the Calabar Flank Epicontinental Sea in Nigeria, leading to the extinction of plants and animals. Notably, the shells of bivalves served as a better indicator of the depositional environment of marine system.
Furthermore, biostratigraphic zones, characterized by various species of Bivalves, Ammonites, Foraminiferas, and Palynomorphs form the basis of the chronology established for these rocks. This phenomenon explains the Global Oceanic Anoxic Events of the Cretaceous times, marked by the deposition of finely laminated organic carbon-rich sediments deposited under oxygen depleted conditions popularly known as the Ekenkpon Shale.
Based on the results obtained, the recovered shells of bivalves’ points to deposition within a shallow marine environment while the dark-grey colour of shales indicate an anoxic reducing environment, together forming a low-energy marine environment.

El pasado 2 de agosto, en la ciudad de Caracas, falleció el querido, respetado y admirado geólogo y profesor Alfredo Mederos Herrera. Su partida deja un profundo vacío en quienes tuvimos el privilegio y el honor de conocerlo. Maestro nato, por vocación de servicio y apasionado amante de las ciencias de la Tierra, quien destacaba por su habilidad para transmitir sus conocimientos de manera sencilla pero entusiasta, siempre salpicada de humor y ocurrencias que convertían incluso los temas más complejos en una experiencia de aprendizaje agradable y memorable.
Como compañero de trabajo, sobresalía por su bonhomía, calidad humana, capacidad para integrarse e integrar a los equipos multidisciplinarios, afabilidad y su constante disposición para cumplir con las tareas de forma eficiente en un ambiente laboral distendido y cálido.

In this paper modeling self inductance of microstripline using knowledge-based neural networks with prior knowledge input and difference methods is presented. Knowledge-based neural networks are compared with radial basis network with respect to accuracy of results and CPU time in execution. It is shown that although less data is used in training of knowledge-based neural networks, more accurate results are obtained with faster convergence in training and although unseen data is used in test of knowledge-based neural networks, accuracy of results is preserved.

In this study, the effects of petroleum generation and expulsion on shale porosity is explored by evaluating the compaction of the Kimmeridge Clay Formation (KCF) within the oil window using log data and shale samples from the KCF within the depth and temperature range of ~1.5-5.0 km and 90-157ºC, respectively. Petrophysical properties e.g porosity and pore-size distribution were measured, and permeability was calculated using empirical models based on the measured porosities. Transit-time values from the sonic logs recorded at depths in the wells were the cores were recovered were calibrated against the porosities determined from the core samples. Bulk geochemical parameters e.g., Total Organic Carbon (TOC), Hydrogen Index (HI) were determined. The volume reduction in the KCF within the oil window due to petroleum generation and expulsion, and compaction due to loss of pore space was determined using the geochemical and log derived porosity data emplaced into empirical relations. Porosities above the oil window range from ~15-20%, but decreased to <5% at the end of the oil window. Pore-sizes decrease from ~11 nm to between 6-8 nm at the depth range of 1.5-5.0 km. Permeability decreased from 4.8 nD to ~0.095 nD. The quantitative estimations of volume reduction within the oil window indicate that for ~8.0wt% initial TOC sediment, a bulk volume reduction of 13% of the initial volume is due to oil expulsion, and ~12% is due to loss of pore space.

This paper exploits variation in the timing and size of oil discoveries to identify the impact of oil wealth on democracy. I use a unique dataset describing worldwide oil exploration, discoveries, and oilfield geology. Controlling for exploratory effort, I find that discovering oil significantly decreases a country's 30-year change in democracy, as measured by the Polity Index. I estimate that, on average, discovering 100 billion barrels pushes a country's democracy level 30 percentage points below trend. Excluding large Middle East producers from the sample does not affect this result. The estimated effect per barrel is larger for oilfields with higher quality oil and lower exploration and extraction costs. To explain these findings, I propose a theory of endogenous barriers to political entry. The deadweight cost of taxing oil is relatively low. To reap the profits from oil, incumbent dictators undertake costly expenditures to prevent entry and to monopolize the state.

The deliberate search for gas to fuel the growing domestic market is a relatively new phenomenon in Indonesia. To date established markets for domestic gas exist in West and East Java, South Sumatra, South Sulawesi and the Medan/Pangkalan Brandan area of North Sumatra. Of these, the Medan/Pangkalan Brandan region faces perhaps the biggest challenge with existing supply from onshore fields in steep decline and growth projections for future energy needs showing a significant shortfall in supply by 2006 even using modest growth projections. In order to satisfy this demand in this, Indonesia&#39;s third largest metropolitan centre, gas will need to be found and found quickly. The Offshore Asahan PSC and Glagah Kambuna TAC lie approximately 20–50 kilometres offshore of the Medan/Pangkalan Brandan region. These contract areas were last significantly explored in the 1980&#39;s when no market for domestic gas existed and exploration efforts focused exclusively on finding oil. Despite three ...

Nicolas GRIMAL et François LARCHÉ Ces neuvièmes Cahiers de Karnak paraissent six ans après les précédents. Les causes de cette longue gestation sont, pour certaines, imputables aux difficultés naturelles que rencontre, sur le terrain, toute entreprise éditoriale. D'autres relèvent de l'anecdote. On nous pardonnera de ne pas nous y attarder. En fait, cette livraison était en préparation depuis trop longtemps. Certains auteurs, lassés, ont repris leur texte. Nul ne pourrait les en blâmer. D'autres ont eu la patience d'attendre des jours meilleurs. Qu'ils soient ici remerciés de nous avoir gardé la primeur de leurs recherches. Il n'en reste pas moins qu'ainsi amputé, ce volume a certainement perdu de l'unité que laissait supposer son sommaire initial. Nous espérons retrouver à l'avenir un rythme plus normal. Les onze articles qui sont présentés ici témoignent toutefois de la vigueur et de la qualité des travaux récents et en cours. Il n'est pas nécessaire de les décrire : le lecteur jugera. On peut insister sur deux apports nouveaux. Tout d'abord, la très importante étude de Luc Gabolde sur la cour de fêtes de Thoutmosis Il est venue renforcer le contenu de notre revue, qui s'était retrouvée vidée de plus de la moitié des contributions prévues au départ. La place que nous lui avons accordée, en tête de l'ouvrage, montre assez le prix que nous attachons à ce beau travail. TI est également un précurseur, puisque nous espérons publier dans un avenir très proche la monographie de Bernadette Letellier et François Larché sur la cour de fêtes de Thoutmosis IV, dont le remontage dans le «Musée de Plein Air» se poursuit actuellement. Deuxième témoignage présentant un des aspects rénovés de l'activité du Centre, le rapport de Catherine Grataloup sur les fouilles qu'elle a menées dans le secteur nord-ouest de l'enceinte d'Amon. Études et restaurations de monuments débouchant, lorsque l'importance de ceux-ci le commande, sur une anastylose dans tous les cas sur une publication exhaustive , et fouille stratigraphique permettant à la fois d'améliorer la connaissance historique du complexe divin d'Amon-Rê et d'en assurer la conservation : voilà les deux axes principaux de la politique scientifique à laquelle s'est attachée l'équipe du CFEETK ces trois dernières années. Chacun des partenaires Organisme des Antiquités de l'Égypte, Direction des Relations Culturelles, Scientifiques et Techniques du Ministère des Affaires Étrangères, Centre National de la Recherche Scientifique s'efforce de fournir les compétences nécessaires à la réalisation de cet objectif. La présente livraison des Cahiers de Karnak reflète cette communauté dans l'effort. Ces intentions, qui ont présidé à la création du Centre, se trouvent ainsi réaffirmées, sans qu'il ait été pour autant nécessaire de remettre en cause les travaux en cours. Les programmes entrepris ces dernières années ont été continués. Certains sont aujourd'hui achevés ou en voie d'achèvement, avec les équipes mises en place à l'origine. De nouveaux programmes ont été définis. Certains ont déjà commencé, d'autres sont dans une phase de VI KARNAK IX préparation. Inversement, des dossiers qui avaient été mis en sommeil et notamment les publications sont en voie de traitement. Le recours aux technologies nouvelles, et, en particulier, à celles relevant de l'informatique, avait été entrepris. Cette direction est toujours suivie, en mettant l'accent sur les besoins actuels de documentation qui sont ceux non seulement de l'Organisme des Antiquités de l'Égypte, mais de l'ensemble de la communauté égyptologique. La documentation inclut naturellement les archives du Centre : un travail de fond a été entrepris, sur le terrain comme au CRA de Valbonne, où Michel Azim continue de rassembler et d'organiser la mémoire de Karnak, pour remonter le retard accumulé ces dernières années et mettre en place un système informatisé. Une attention toute particulière est également apportée aux questions de préservation des monuments, mais aussi aux problèmes que soulève la «gestion touristique» du site le plus visité d'Égypte. * **

A region of chaotic and disturbed seismic is recognized in the central Yinggehai / Song Hong Basin. Combined with gravity data, shale diapir distribution, AAT regression, and AAT geochemistry, this area may be the Australasian Tektite source crater.

Seven representative crude oil samples from the Gulf of Suez were chosen for this study. The studied crude oils are Ras Badran, Belayim marine, Belayim Land, Rahmi, West Bakr, Esh El Mellaha and Geisum. The oils were fractionated by medium pressure liquid chromatography into saturated hydrocarbons, aromatic hydrocarbons and polar compounds. The saturated hydrocarbons were determined by gas chromatography and gas chromatography/mass spectrometry (GC/MS). Ratios of certain biomarkers, (Pristane/phytane, isoprenoids/nalkanes, CPI, Homohopane, Diasteranes, Gammacerane index, C 29 20S/20S+20R, C 29 /C 30 hopanes and Ts/Tm) referred to as source correlation indices, are sensitive to the geological source of oil. The results of evaluation suggest that two types of oils could be recognized as marine oils. These oils are characterized by high level of maturation and sourced mainly from source rocks rich in marine organic matters with few inputs from terrestrial origin.

This paper represents the first comprehensive survey and provides important data on PAHs concentration and composition in Alexandria coastal seawater. The compositions of PAHs determined in all samples are to be used as chemical markers for identifying different sources of PAH pollution in the surface seawater of Alexandria coastal area. The quantitative analysis of PAHs showed a concentration ranging from 8970.939 to 1254756.00 ng/L, which exceeds the maximum admissible concentrations of PAHs (200 ng/L) for the water standard of European Union. The calculated diagnostic ratios suggested that the sources of PAHs at the majority of the studied area are derived primarily from pyrogenic sources from incomplete fuel combustion of the boats and vehicle engines with lesser amounts of PAHs contributed from petrogenic sources. Some stations displayed mixed sources in comparison to many other studied marine systems, the PAH concentrations detected at Alexandria area were considered to be higher and pose health risks to aquatic bodies.

The present work deals with the identification of the potential and generating capability of oil generation in the Jurassic source rocks in the Salam-3x well. This depending on the organogeochemical analyses of cutting samples representative of Masajid, Khatatba and Ras Qattara formations, as well as, representative extract samples of the Khatatba and Ras Qattara formations. The geochemical analysis suggested the potential source intervals within the encountered rock units as follows: Masajid Formation bears mature source rocks and have poor to fair generating capability for generating gas (type III kerogen). Khatatba Formation bears mature source rock, and has poor to good generating capability for both oil and gas. Ras Qattara Formation constituting mature source rock has good to very good generating capability for both oil and gas. The burial history modeling shows that the Masajid Formation lies within oil and gas windows; Khatatba and Ras Qattara formations lie within the gas window. From the biomarker characteristics of source rocks it appears that the extract is genetically related as the majority of them were derived from marine organic matters sources (mainly algae) deposited under reducing environment and take the direction of increasing maturity and far away from the direction of biodegradation. Therefore, Masajid Formation is considered as effective source rocks for generating hydrocarbons, while Khatatba and Ras Qattara formations are the main source rocks for hydrocarbon accumulations in the Salam-3x well.

The present work deals with subsurface geology, the identification of the potential and generating capability of oil generation of some Jurassic and Lower Cretaceous formations in the North Western Desert were investigated by studying the composite logs for seven wells. Jurassic units include; Ras Qattara, Khatatba and Masajid formations. Ras Qattara and Khatatba formations are not recorded in the investigated wells except at Salam-3X well. Lower Cretaceous units are represented in this work by Alam El-Bueib Formation. Isopach and lithofacies maps and lithostratigraphic correlation charts of these formations are constructed and discussed in order to distinguish the shape, the extent of sedimentary basins and the environment of deposition. Isopach maps showed that the thickness of Masajid sediments increases toward the northeastern and western directions and the thickness of Alam El-Bueib sediments increases toward the eastern and western directions. Triangle facies maps showed that limestone (non-clastic) facies are predominance in Masajid Formation reflecting open marine depositional environment and argillaceous sandstone facies are predominance in Alam El-Bueib Formation reflecting terrestrial to shallow marine depositional environment. The geochemical analysis results showed that Ras Qattara Formation constitutes a mature source rock have good very good generating capability for both oil and gas. Khatatba Formation bears a mature source rock, and has poor to good generating capability for both oil and gas. Masajid and Alam El-Bueib formations bear mature source rocks and have poor to fair generating capability for generating gas (type III kerogen). The burial history modeling shows that Ras Qattara and Khataba formations lie within the gas window, Masajid Formation lies within oil and gas windows and Alam El-Bueib Formation is still within the early stage of hydrocarbon generation. Therefore, Ras Qattara and Khatatba formations are the main source rock for hydrocarbon accumulations at Salam-3X well. Masajid and Alam El-Bueib formations are also considered as effective source rocks for generating hydrocarbons.

The subsurface study and evaluation of the Cretaceous and Miocene rock units in Ras Gharib oil field in the central Gulf of Suez were investigated by studying the composite logs for ten wells through the constructing of isopach, lithfacies maps and stratigraphic cross sections (lithostratigraphic and structural) of some rock units, in order to distinguish the shape and the extent of sedimentary basins and the environment of deposition. On the other hand, we have analyzed twenty five ditch samples collected from five wells using Rock Eval-6 pyrolysis for the determination of the total organic carbon and organic geochemical characteristics of these samples. The Cretaceous units includes; Nubia "A", Raha and Wata formations .The Nubia "A" Formation is deposited in terrestrial to shallow marine environment and has two main depocenters of deposition at the south eastern and south western directions. While, Raha and Wata formations are deposited in shallow marine environment. The thickness of Raha Formation increases towards the north and south eastern directions and Wata Formation has two main depocenters at the south eastern and north western directions. The Miocene units includes; Basal Miocene Bed (Nukhul), Belaiym and South Gharib and Zeit formations. Basal Miocene Bed Formation is deposited in shallow marine environment. Meanwhile, Belayium Formation is deposited in deep to shallow marine environment. In contrary, the South Gharib and Zeit formations were characterized by lagoonal facies. The thickness of Basal Miocene Bed Formation increases towards the north western direction and from the west to east direction in Belaiym Formation. Moreover, South Gharib and Zeit formations are characterized by one main depocenter of deposition. Total organic carbon and pyrolysis analysis of the Cretaceous and Miocene source rocks revealed that the Cretaceous formations are immature source rocks, ranged from fair to good source rocks and have kerogen of type III and type III/II. Meanwhile, Miocene source rocks range from immature to marginally mature source rocks, are considered to range from good to very good source rocks for potential generation of both oil and gas and are characterized by kerogen of type III/II and type II.

The present study has clearly demonstrated that seeding a petroleum hydrocarbon polluted sea water with a halotolerant Pseudomonas aeruginosa Asph2 and corn steep liquor as a cheap and readily available source of nutrients significantly enhances the progress of biodegradation BD of petroleum hydrocarbon pollutants. There was a statistically high significant difference between natural weathering NW and both bioaugmentation BA (p = 2.92e-14) and biostimulation BS (p = 3.56e-13) at 95% confidence interval (a = 0.05). BA significantly improved the efficiency of total petroleum hydrocarbon TPH and the recalcitrant asphaltene degradation by % 23 and 17% compared to BS process (p = 2.0693e-5 and p = 1.4e-3, respectively). The BD of biomarkers; pristane Pr, phytane Ph, and terpanes were very apparent. The BD of C28 tricyclic terpane, C27 13b, 17a-diasterane (20S), and C30 17a, 21b-hopane were higher than that of C35 17a,21b-homohopane. The BD of C27 18a(H)-22,29,30-trisnorneohopane (Ts) was higher than that of C27 17a(H)-22,29,30-trisnorhopane (Tm). The BD of sterane was higher than that of hopane. C30 18a-Oleanane was more resistant to degradation than other compounds.

Abstrak Aluminium sulfat merupakan zat kimia yang memiliki sifat yaitu tidak berbau, tidak berwarna, dan juga aman untuk digunakan. Selain itu ia juga memiliki sifat yang mudah mengkristal. Kristal dari aluminium sulfat biasanya digunakan sebagai bahan pengamatanproses kristalisasi karena bahannya yang murah dan mudah dicari. Selain mudah untuk mengkristal, prosesnya pun juga cepat. Sifat-sifat dari kristal aluminium sulfat ini adalah berbentuk oktahedron (dua piramid yang berhadap-hadapan) dan berwarna bening. Pada penelitian kali ini adalah berjenis ekplorasi, dengan menggunakan metode eksperimen agar hasil yang didapatkan lebih beragam. Setelah dilakukan berbagai eksperimen, hasil kristal terbaik didapatkan dengan melarutkan 35 gr aluminium sulfat ke dalam 200 ml air distilasi yang bersuhu 70°C selama 48 jam. Dari formula yang didapatkan itu baru dimodifikasi lagi dengan berbagai tambahan seperti pewarnaatau lainnya. Dari situ didapatkanlah hasil yang lebih beragam seperti krista...

The Eagle Mills Formation is known to contain organic-rich lacustrine source rocks along the peripheral graben system of the northern Gulf of Mexico Basin. This formation is characterized by Late Triassic-Early Triassic aged fluvial to lacustrine facies and syn-rift sediments, which record the early development of the basin. To interpret the early development of the basin, the whole-rock mineralogy, geothermal gradient, porosity, and fluid saturation of the Eagle Mills Formation was determined to identify vertical heterogeneity and depth-dependent properties not previously known. Considering this, data on the Eagle Mills is sparse and not very well documented. However, cuttings data managed at the Mississippi Department of Environmental Quality (MDEQ), provide a narrow volume of material to analyze under natural thermal and geochemical conditions. Based on X-ray powder diffraction (XRD) for a well located in Newton County, Mississippi, the Eagle Mills is primarily composed of detrit...

Among all the methods used for determining fluid saturation of the reservoir rock, the ability of neural networks to predict fluid saturation in reservoir rock is of great interest to researchers. This study gathers the necessary data for estimating this important reservoir parameter and the variables involved in the process. Afterward, artificial neural networks (ANNs) and particle swarm optimization (PSO) algorithms are combined to provide a proper and accurate model for estimating water saturation. This combination provides an outstanding model in which fluid saturation distribution at any point in one of Iran's carbonate oil reservoirs can be obtained. To predict the water saturation value as the model output, several input parameters, including depth, gamma ray, resistance, neutron, micro-spherical resistance, and spontaneous potential logs, are employed. The multi-layer perceptron neural network (MLP) and radial basis function neural network (RBF) are the two models used, and the accuracy of each model is examined. Although the relationship between fluid saturation in the reservoir and logging information is completely nonlinear, these two artificial intelligence (AI) models can very well recognize this nonlinear relationship and provide great predictions with high correlation coefficient (R) values and low average absolute relative deviation (AARD) and root mean square error (RMSE) values. The values of R, AARD, and RMSE for the MLP model are obtained as 0.9739, 33.24, and 0.0824, respectively. Those for the RBF model are 0.9986, 7.47, and 0.0024, respectively, reflecting that the RBF model is superior to the MLP model due to its higher R value and lower AARD and RMSE values.

Background and Objective: The Asmari fractured reservoir in Iran presents significant challenges for reservoir characterization due to complex structural heterogeneities and the presence of tar. Conventional techniques such as core sampling and standard logging often fall short in predicting permeability and production behaviour within such intricate reservoirs. This study integrates formation micro imager (FMI) data with petrophysical analysis to assess fracture properties, permeability, and evaluate the impact of tar on reservoir performance. Materials and Methods: The MI logs, combined with conventional petrophysical logs, were employed to analyse structural dips, fracture orientations, and reservoir heterogeneity. Bright and conductive features in FMI images were examined using sinusoid fitting techniques, and heterogeneity indices were computed via specialized software. Permeability analyses compared FMI-derived indicators with core measurements, while tar effects were assessed through resistivity contrasts and gamma log responses. Results: Structural analysis identified dips of approximately 46° towards S20W and fracture strikes oriented N83E-S83W. Longitudinal open fractures, predominantly in Zones 6 and 7-1, exhibited apertures up to 1 mm. High FMI resistivity values within porous dolomite layers correlated strongly with the presence of tar and heavy oil, causing permeability overestimation and impaired fluid mobility. Despite elevated porosity in carbonate and dolomite sections, tar occupation of pore spaces significantly reduces effective permeability. Conclusion: The FMI logging offers critical insights into fractures, heterogeneity, and permeability variations influenced by tar saturation. These findings advance the understanding of the Asmari reservoir's complex carbonate framework, facilitating optimized production strategies for fractured, tar-affected reservoirs.

This paper is a proposed deep learning application to do integrated petrophysical, pore pressure and geomechanics property prediction in unconventional hydrocarbon reservoirs. Simple modeling methodologies in use do not help much in capturing the non-linear multi-attribute interactions that were common in the subsurface conditions (particularly the complex formation in the Permian Basin). To give concurrent estimates of porosity, permeability, pore pressure, Youngs modulus and Poissons ratio, this paper creates a multi-output deep feed forward neural network that is trained on both well logs and seismic-derived properties. Large volumes of preprocessing, feature engineering, and optimization algorithms were used to improve the amount of accuracy and generalizability of models. It tests well on the results which proved to have excellent predictive performance when compared with the traditional deterministic models in terms of accuracy, time-efficient and scalability. SHAP and sensitivity analysis are techniques to interpret the model and prove any geological relevance of its predictions. Moreover, volumetric modeling made on the seismic data enabled the extension of the prediction beyond the wellbore-level to the full-field. The paper offers the possibilities of applying deep learning to transform the way of reservoir characterization, decrease turnaround time and enhance decisionmaking associated with developing unconventional resources.

Applied organic geochemistry provides the information needed to make maps of the richness, type, and thermal maturity of a source rock. These maps are a necessary step toward determining the stratigraphic and geographic extent of a pod of active source rock in a petroleum system, and they are based on geochemical analyses of rock samples from outcrops and wells that are displayed on logs. These geochemical well logs are based on Rock-Eval pyrolysis, total organic carbon, vitrinite reflectance, and other rapid, inexpensive "screening" methods. The logs define (1) potential, effective, and spent petroleum source rock; (2) the thermal maturation gradient, including immature, mature, and postmature zones, and (3) in situ and migrated petroleum shows. Useful geochemical logs require proper sample selection, preparation, analysis, and interpretation. Detailed studies, including oil-source rock correlations by biomarker and supporting techniques, are undertaken on selected samples only after the screening methods are completed.

HAL is a multi-disciplinary open access archive for the deposit and dissemination of scientific research documents, whether they are published or not. The documents may come from teaching and research institutions in France or abroad, or from public or private research centers. L'archive ouverte pluridisciplinaire HAL, est destinée au dépôt et à la diffusion de documents scientifiques de niveau recherche, publiés ou non, émanant des établissements d'enseignement et de recherche français ou étrangers, des laboratoires publics ou privés.

The Zagros Fold and Thrust Belt in Iraq contain host prolific hydrocarbons and recently, significant oil reservoirs have been discovered in the Jurassic carbonate rocks. The current work focuses on Water and Hydrocarbon Saturation in the carbonate rocks of the Sargelu Formation (Middle Jurassic) based on a set of conventional Wireline logs which are: Gammaray, Neutron porosity, Bulk Density, three sonic types, all Resistivity, photoelectric, uranium, thorium, and potassium. The Wireline log shows that the Sargelu Formation can be divided into five units based on lithology. These units were derived from different cross plots. The computation of petrophysical properties of this carbonate reservoir is complex due to several washouts and heterogeneities, caused by the exposure of shale which is strongly influencing the reservoir saturation. The Wireline log shows that the average Water saturation in the carbonates of the Sargelu Formation is 20%, with an irreducible Water saturation of 0.2% and an average Hydrocarbon saturation of 30%. Whereas, the water resistivity is 0.03 ohm.m and the Mud filtration resistivity is 0.17 ohm.m.

Petrophysical properties of the Early Cretaceous Sarmord and Garagu formations from the Atrush and Sarsang Blocks in the Kurdistan Region are studied. These formations are generally composed of limestones and dolomitic limestones interbedded with thin to medium layers of yellowish-gray marl (calcareous mudstone). The current study shows that the average shale volume in the Sarmord and Garage formations is between 16% and 20%. In Atrush-1 Well, the average porosity ratio of the Sarmord and Garagu formations is fair to good (15% and 11%, respectively). However, in Mangesh-1 Well, the porosity value is poor; it is around 4% on average. Generally, most of the hydrocarbons that have been observed within the pore spaces are residual oil type in Atrush-1 Well and movable hydrocarbon type in Mangesh-1 Well. In Atrush-1 Well, out of 362 m thickness of both formations, only 180 m is considered to be a pay zone; whereas, the pay zone is just around 8.0 m thick out of 347 m of the total thickness. According to the calculated porosity values, the Garagu and Sarmord formations are not considered as good reservoirs in the studied wells, with the exception of Atrush-1 Well where the Sarmord Formation has fair potential reservoir characteristics.

Digital Twin (DT): the Digital Twin is a set of virtual information constructs that fully describes a potential or actual physical manufactured product from the micro atomic level to the macro geometrical level. At its optimum, any information that could be obtained from inspecting a physical manufactured product can be created before there is a physical product. The ideal is that we would like to develop the Digital Twin, test it to ensure that it produces the behaviors we desire, manufacture it digitally to make it as lean as possible, then use and support it digitally, simulating it throughout its life cycle. Only when we are convinced that the product design meets all our requirements, we would then make the physical product. Again, if we are seeking the ideal, we would print it using Additive or 3D Manufacturing! Clearly the complexity of the product drives the amount and types of data and information needed. A paper clip doesn't need a DTP. A 21st century fighter jet needs a substantial and complex DTP. Digital Twin Instance (DTI): this type of Digital Twin describes a specific corresponding physical product that an individual Digital Twin remains linked to throughout the life of that physical product. Depending on the use cases required for it, this type of Digital Twin may contain many different types of information: geometrical information, service information, part changes, etc. Digital Twin Aggregate (DTA): this type of Digital Twin is the aggregation of all the DTIs. Unlike the DTI, the DTA may not be an independent data structure. It may be a computing construct that has access to all DTIs and queries them either ad-hoc or proactively.

Faghur Basin is one of the most important hydrocarbon provinces in the northern Western Desert of Egypt. Some of the Mesozoic (Alam El Bueib and Khatatba formations) and Paleozoic rocks at this basin were evaluated as source rocks based on certain parameters including: the quantity, quality and maturation of the contained organic matter. PetroMode 1D software was used for the construction and prediction of geological and geochemical models. Results from organic geochemical analysis have clarified that the TOC, HI, S1, S2, %Ro and Tmax values of Alam El Bueib source rock units range from 0.27 to 6.39 wt.%, 34 to 114 mg/g, 0.12 to 0.38 mg/g, 0.23 to 4.3 mg/g, 0.58 to 1.07 % and 409 to 450 o C, respectively. While for the Khatatba source rock these values range from 0.41 to 30.09 wt.%, 27 to 155 mg/g, 0.1 to 0.53 mg/g, 0.15 to 26.41 mg/g, 1.02 to 1.09 %, 363 to 454 o C, respectively. As for the Paleozoic source rock they are ranging from 0.53 to 4.83 wt.%, 52 to 136 mg/g, 0.06 to 0.4 mg/g, 0.29 to 6.57 mg/g, 0.97 to 1.1 % and 406 to 467 o C, respectively. Such results indicate that the Alam El Bueib source rocks are characterized by type (III) kerogen while Khatatba and Paleozoic source rocks are of type (III) kerogen with inputs of kerogen type (II). Burial history analysis indicates that most of these source rocks are mature and reached their maximum temperature at Neogene time.

Safed-koh Trend is located in D.G.Khan district, Punjab province, Pakistan. It is a north south trending fold belt that lies in Eastern Part of Sulaiman Fold Belt. Seismic data correlation is done with the help of well data, Formations' tops, Synthetics and general stratigraphy of the area. The Structural and Stratigraphical interpretation shows subsurface variations. Depth model shows Dhodak, Rodho, Afiband and Zindapir anticlines, the four culminations of Safed-Koh Trend without marking the faults. Dhodak is a northern lower most culmination. Zindapir is the most uplifted one and broader structure comparatively that lies at southern edge. 3D subsurface Time & Depth models of Rubbly Limestone, Dunghan Formation, Pab Sandstone, Lower Goru Formation and Chiltan Limestone map Dhodak anticlinal structure with reverse faults at its flanks. Dunghan, Ranikot, Pab and Chiltan Formations in this area have already proved to be good quality reservoirs for gas. Pab Sandstone and sands of Lower Goru Formation of Cretaceous and Chilton Limestone of Jurassic age could also be the important reservoirs in unexplored area. Rock Physics analysis of Chilton Formation confirms the hydrocarbon potential.

The Upper Jurassic Smackover Formation is found in an arcuate belt in the subsurface from south Texas to panhandle Florida. The Smackover is the most prolific hydrocarbon-producing formation in Alabama and is an important hydrocarbon reservoir from Florida to Texas. In this report Smackover hydrocarbon reservoirs in southwest Alabama are described. Also, the nine enhanced-and improved-recovery projects that have been undertaken in the Smackover of Alabama are evaluated. The report concludes with recommendations about potential future enhanced-and improved-recovery projects in Smackover reservoirs in Alabama and an estimate of the potential volume of liquid hydrocarbons recoverable by enhanced-and improved-recovery methods from the Smackover of Alabama. The Smackover was deposited on a carbonate ramp, similar to that of the present-day Persian Gulf, in much of the Gulf-Coast region. However, in southwest Alabama, Smackover strata were deposited in four interconnected basins' the eastern part of the Mississippi interior salt basin, the Manila embayment (which contains two separate depocenters), the Conecuh embayment, and a basinal area south of the Baldwin high. The distribution of facies was more closely controlled by local paleotopography than by southerly regional dip, as would have been the case in an unmodified ramp setting. High-energy facies were deposited in nearshore areas rimming exposed paleohighs and near the updip limit of Smackover deposition; lower energy strata were deposited in basin centers. Based on ammonites recovered from the lower portion of the unit, the Smackover has been assigned a late Oxfordian age. The Smackover ranges up to more than 550 feet thick in the study area. Basal Smackover strata in Alabama contain laminar and domal stromatolites; these deposits probably formed in shallow water during the early stages of marine transgression. Middle Smackover strata are dominated by lime mudstone and pelletal or fossiliferous lime wackestone. These strata were deposited at and near the time of maximum transgression, and during and after a period of rapidly increasing water depth. Middle-Smackover lime mudstone is typically laminated and organic rich. Upper Smackover strata were laid down during a relative sea-level stillstand. Progradational strata of the upper Smackover are dominated by ooid grainstone and diverse peritidal carbonates on the flanks of the paleohighs and by pelletal and oncoidal packstone and grainstone in the centers of the depositional basins. The Smackover locally contains substantial amounts of siliciclastic material, particularly near the Conecuh ridge and its associated small paleohighs (e.g., Barnett, North Wailers Creek, Uriah, Vocation, and Burnt Corn Creek fields) and in the Manila embayment. Diagenesis of Smackover reservoirs was dominated by the effects of (1) early cementation, (2) leaching of calciumcarbonate allochems, and (3) dolornitization, both mimetic and nonmimetic. The Smackover Formation is overlain in south_est Alabama by the Buckner Anhydrite Member of the Haynesville Formation, whose basal portion is dominated by subaqueous evaporites in depositional basins, and by peritidal and supratidal evaporitic and siliciclastic strata on the flanks and crests of paleohighs. As of December 1990, the Smackover had produced oil, condensate and/or natural gas from 73 established fields in Alabama. At that time, cumulative production from Smackover reservoirs in Alabama totaled over 113 million barrels (MMB) of oil (including Norphlet oil production at South Womack Hill field and minor amounts from a few other fields, which are not reported separately), 145 MMB of condensate (including Norphlet condensate production at Hatter's Pond field, which is not reported separately), and 1.12 trillion cubic feet (TCF) of natural gas. Smackover hydrocarbon traps in southwest Alabama can be characterized as structural or combination structural and stratigraphic traps. Many structural traps result from halokinesis of the Louann Salt, but basement-cored anticlinal traps are locally common. The Buckner Anhydrite Member of the Haynesville Formation commonly forms the seal. Combination traps generally involve porosity or permeability pinch-outs occurring on regional dip, on halokinetically generated anticlines or structural noses, or on basement-related anticlines or faulted anticlines. Most Smackover reservoirs originated as nearshore-marine carbonate sediments with minor admixtures of noncarbonate material. Some of these reservoirs preserve abundant evidence of their environment of deposition. Others have been highly altered and their origins are unclear. The most VIII II' I_ '' '_ ' " " II '_' ' _ m "' "11_, .... , ........ pl II recovery under secondaryrecovery is expected to be 13 million barrels over what would have been producedunder primary depletion. FannyChurchfield, in EscambiaCounty, was alsounitized in 1985. A nitrogen-injection program was commenced in a portion of the field. Primary recovery was estimated to be 3.9 million barrels. However, using nitrogen injection, 7 million barrels could be recovered.Through 1990, 4.3 million barrelsof oil have been recoveredfrom the unit. Approximately 9.3 billion cubic feet of gas have been injected into the Smackoverreservoir although no injection operationsare ongoing. Unitized fields are found in each of the pore facies defined by Kopaska-Merkel and Mann (1991). Within the moldic pore facies, only strategic well placement has been used. Gas injection and infill drilling are the only enhanced-or improved-recoverytechniques used in the intercrystalline pore facies.Enhanced-or improved-recoverymethods used in reservoirswith intermediate pore systems include infill drilling, strategic well placement, waterflooding, and gas injection. However, poresystemcharacteristicsshould not necessarilyrestrict the type of enhanced-or improved-recovery methods used. Injection operations should be considered for fields in the moldic pore facies and strategicwell placement is a viable option wherever hydrocarbonsare updip from existingwells.Also, reservoirswith intercrystallineand moldic pore systemsshould be evaluated for multiple enhancedor improved-recoverytechniquesashave been implemented in Jay-LEefields. Unitized fields with intermediate pore systemshave produced over 435 million barrels of oil (includingthe Floridaportion of Jay-LEC fields).The intercrystalline pore facies has producedapproximately 90 million barrels of liquid hydrocarbonsfrom unitized 5mackoverfields. Approximately 11 million barrelsof hydrocarbonliquidshave been producedfrom unitized reservoirswithin the moldic pore facies. Potential candidates for enhanced or improved recovery are identified based on similaritiesto fields already unitized. Strategicwell placement is the most viable improved-recovery technique for medium to small reservoirswhere injec*.ionoperations are economicallyprohibitive. By drilling wells at strategic locations portions of the reservoir that would not be drained by existing wells can be penetrated and hydrocarbon,ecovery increased.Fields that should be consideredfor strategicwell placement includeMovico, Blacksher,Barrytown, and North Choctaw Ridge. Candidatesfor injection includeMovico,BigEscambiaCreek,and North Choctaw Ridgefields. The combined estimates, made by operators prior to enhanced-or improved-recovery' operations, for secondaryproductionfrom the nine Alabama Smackoverfields currently undergoing suchoperations, amount to 331.5 million barrels of hydrocarbon liquids. Revisionof this estimate based on (1) results of enhanced-and improved-recoveryoperations through 1990, (2) proposed tertiary recoveryfrom some of these nine fields using reasonable estimates of relevant parameters from thi_ _aport and from the publishedliterature, and (3) proposedenhanced or improved recovery from potential candidates listed above, yields a new estimate of 468 million barrels of liquid hydrocarbons expected to be produced by enhanced-or improved-recovery methods from the Alabama Smackover.Eventhis estimate isprobablyconservative.

Reservoir characterization of the upper part of Qamchuqa Formation at the wells of Miran West-2 (MW-2) and Bazian-1 (BN-1) is studied. This formation typically has low shale content at the BN-1 well. At the same time, in the MW-2 well, the middle part of the studied formation is dominated by shaly and shale intervals, possibly affected by the Sarmord and Balambo depositional environments. Although the upper part of Qamchuqa Formation is mainly composed of dolomite with minor dolomitic limestone, marl and shale are occasionally present. Furthermore, porosity values are commonly less than 15% in both wells; nevertheless, there are a few intervals where porosity significantly increases. The formation at the BN-1 well has a higher porosity than the MW-2 well. Moreover, the secondary porosity is relatively low as 4.0% at the MW-2 well, while in the well of BN-1, it ranges between < 4.0% and 7.5%. The measured permeability of the formation suggests good permeability. According to the shale volume, porosity, and permeability, the upper part of Qamchuqa Formation is subdivided into three reservoir units. RU 1 at the MW-2 well and RU 2 at the BN-1 well have the most substantial reservoir properties. However, the lowest reservoir quality appears within RU 1 of the BN-1 well and RU 2 at the well of MW-2. Additionally, residual hydrocarbons constitute an extensive fraction of the pore spaces, while tiny portions of the moveable one can be discovered along all reservoir units of the formation. Finally, considering the hydrocarbon movability of the MW-2 well, the upper part of Qamchuqa Formation is defined by primarily movable oils in RU 1 and 2. In contrast, moveable oils are detected in almost all of the reservoir units of the BN-1 well.

The quality of any reservoir is strongly controlled by diagenetic processes, especially of those that are comprised of mixed siliciclastic-carbonate sequences. An Eocene mixed siliciclastic-carbonate sequence forms reservoirs with diverse reservoir quality in the Hungarian Palaeogene Basin, which is found within the Pannonian Basin. Late Eocene transgression established extensive shallow-marine depositional environments strongly controlling the early diagenetic processes. Drill cores and cuttings were selected from several boreholes, representing a wide range of lithofacies to reveal the cause for reservoir heterogeneity. Petrographic, stable isotope and fluid inclusion analyses were performed to identify the diagenetic processes that controlled the porosity evolution of the reservoir, The early diagenetic calcite neomorphism caused lateral homogeneity, whereas the early meteoric water incursion enhanced reservoir properties via the development of dissolution pores, which in turn resulted in vertical reservoir heterogeneity. The deterioration of porosity started in the eogenetic realm by kaolinite formation and continued during mesodiagenesis as burial calcite, quartz, dolomite and minor illite cement precipitated in remaining pore spaces. Petrographic evidence, such as kaolinite transformation into dickite and fluid inclusion homogenisation temperatures highlight the role of temperature increase with burial, the effect of changing fluid chemistry during the evolution of the basin is documented by the chemical zonation of dolomite, the variation in salinities of the fluids enclosed fluid inclusions, as well as recurrent and prolonged periods of cementation with calcite, quartz and dolomite. Mesogenetic processes were accompanied by hydrocarbon emplacement and the formation of late-stage pyrite. The propagation and cementation of faults first contributed to increase and later to reduce fluid flow, respectively. These steps collectively resulted in a heterogeneous reservoir, characteristic of the Eocene sequence in the Hungarian Palaeogene Basin.

Present study evaluates the Farewell Formation which is an important reservoir of the Kupe Field, located in the southern Taranaki Basin, New Zealand. It includes petrographical and well log analyses coupled with impact of diagenesis on the reservoir quality of Kupe Field. The petrographical study was carried out on Kupe South‒1, Kupe South‒2, Kupe South‒3, Kupe South‒4 and Kupe South‒5 wells by considering datasets and designing cross plots between different petrographical parameters e.g. grain size, porosity, permeability and the total cement concentrations etc. The study indicates that Farewell sandstone are ranging from Feldspathic arenite to Lithic arenite. Detrital mineralogy is dominated by quartz and feldspar. The total porosity within the Farewell Formation ranged between 10.29‒26.2% while the permeability ranged between 0.43‒1376 mD, thus showing good to very good reservoir quality. Petrophysical analyses from Kupe‒1, Kupe South‒2, Kupe South‒5 and Kupe South‒7 wells helpe...

Health services are essentially social services. It is one of the many services system that has emerged to facilitate of individual as well as social goals. Health is one of the major dimensions in socio economic development. The main objectives of the study are; To analyse the spatial distribution of primary health care centre in Madurai district. To analyse the socio-economic conditions of patients in Madurai district. To analyze the patient perception and satisfaction level who avail these PHC services. The study area Madurai district lies between 9° 30′ north to 10° 30′ North latitudes and 77° 30′ east to 78° 30′ East longitudes. The data for the present study was collected from primary and secondary source. The random sampling technique is adopted to collect the primary data in all 13 blocks of Madurai district. Altogether about 260 sample respondents have been interviewed from the study area for the Questionnaire method. The data has been analysed by means of Descriptive statistical techniques. To identify health service area in Madurai District, spatial analysis techniques were applied. A detailed fieldwork was carried out at all levels to study the socio-economic characteristics of the respondent and their utilization pattern.

      The Hartha Formation reservoir was evaluated to be produced in the near future in Y oil and J fields, West of the Tigris River in northern Iraq. Due to geological data analysis of the Hartha facies and diagenesis could enhance oil production with minimized risks, this research tried to deal with data to support the oil production. The Hartha reservoir is subdivided into five-rock units, Har-1, 2, 3, 4 and 5. It is of Heterogenic facies limestone, dolomite, dolomitic limestone and argillaceous dolomite. The Hartha Formation is a clean carbonate; it has an effective porosity. It consists of lime mudstone-packstone skeletal grain. This conclusion is based on the lithology, core microfacies, cutting, thin section and log interpretation variability.   The study aims to characterize the depositional and diagenetic properties of the Hartha carbonate and their effects on the reservoir quality. This research indicated that the depositional setting is a gentle slope ramp including outer...

Afield development plan (FDP)  of the Y and J oil fields for cretaceous reservoir (Harth Formation) evaluation and the production of hydrocarbons in the near future in two Y and J oil fields. Open hole logs namely (Gamma ray, Resistivity, Sonic, Caliper and Density) logs were used to determine petrophysical parameters. The parameters determined are; volume of shale, porosity, water saturation, irreducible water saturation and bulk volume of water. The thickness of the reservoir varies between (40 and 120) m. Determining the porosity depending on the porosity of the log (16-28)%  and core  Average porosity (18-37)% values vary between; generally decreasing with depth. Average porosity 33.3%.test is flow crude oil 1000 bll /d.in J field basically water saturation calculation5-16%. And oil saturation (90-80) % and the oil were carried out at a rate of 1000 barrels / day in the complete test of well Y. The amount of the original oil storage OOIP (1039 * 10^6) standard cubic meters. This...

The Upper Campanian Hartha Formation represents potential Cretaceous hydrocarbon-bearing reservoir rocks across the Y and J oilfields northwestern Zagros Basin, northern Iraq. The study objective is depositional environment which affects reservoir properties by tool, lithofacies, core, thin section, and logs, using petrel (V.2016) and strat software, facies distribution, grains, and diagenetic processes control and enhance reservoir properties which can plan platform production and minimize risks in choosing production wells location at two fields scale The current study is concerned with lithofacies and microfacies of the Hartha Formation within two fields in northern Iraq. Several subsurface well-log data, core, and cutting samples have been used in order to prepare thin sections that were subjected to sedimentological (lithofacies, and grain-size) examination. The petrography investigation revealed five rock-units including Hr. 1, 2, 3, 4, and 5, the thickness of 89 m in the Y-A ...

Authigenic kaolin is a major occluder of porosity at all depths in the Hutton-NW Hutton Brent Group reservoirs. Two polytypes, kaolinite and dickite, are present. Kaolinite occurs to a depth of ∼10,600 ft and is interpreted to be eogenetic. Dickite increases in abundance with burial depth, concomitant with increasing K-feldspar dissolution. Kaolin petrography indicates that kaolinite transforms to dickite via dissolution-reprecipitation at depths of ∼11,000 ft. Dickite has δ18O values characteristic of modified meteoric water for growth at temperatures of contemporaneous quartz authigenesis.Palaeohydrodynamic models involving meteoric water penetration down to 2 km through faults or Palaeozoic rocks of the East Shetland Platform are unlikely to provide the vigorous fluid throughput required for kaolin precipitation. Reverse post-rift modelling indicates that the crest of the Hutton-NW Hutton fault block was not sub-aerially exposed, precluding meteoric water ingress via this route. ...

Although reservoir characterization has been carried out by many researchers on the sedimentary package of the Bengal basin hydrocarbon province, integration of petrophysical and seismic sequence-based reservoir evaluation is rarely taken into account. This paper focuses on the identification of gas zones, reserve estimation and identification of new prospects in Srikail gas field within the eastern fold belt of Bengal basin integrating four wireline logs and 2D seismic data. Our study finds seven hydrocarbon-bearing zones (A, B, C, D, E, F and G) within the measured depth between 2429.5 and 3501 m. Petrophysical properties of seven hydrocarbon-bearing zones indicate that they are good quality reservoir sands. The gas horizons were mapped on seismic sections which reveal that the NW-SE anticlinal structure is largely affected by channels in the crest and western flank. The channels are infilled by fine-grained sediments which act as cap rock on northern and western parts of the structure. Thus, the anticlinal structure and fine-grained sediments make a potential trap for hydrocarbon accumulation and laterally and vertically well-distributed sequence remnants are the main reservoir rocks in this area. Volumetric reserve estimation of these sands provided a total gas initially in place as 552 billion cubic feet. Moreover, all the four wells are drilled in the southern block of the structure, and since there is a structural continuity from south to the north, it is highly recommended to drill a well up to 3000 m depth in the northern block to test its hydrocarbon potentiality. Overall, the outcomes of this study contribute new insights for reservoir characterization and identification of new prospects in an efficient way.

This study aims to share the data of the Ottoman provinces of Mosul,
Baghdad and Basra under 19 headings in a previously unseen Ottoman
document, which is considered to have been prepared to inform Sultan
Abdulhamid about the international political environment and conjuncture of the time in which the Ottoman State was located in the 19th century, and to provide a wide range of comprehensive information about the Ottoman country and society using modern statistical methods of the time. In addition to assessing this data, it is also aimed to review the status of statistical science in the Ottoman State in the 19th century based on our examinations of the document and its author. It is evaluated that the document in question is valuable and important in terms of showing the functioning of the state organization of the period in the Ottoman Empire, seeing the reflections of the changes that occurred in the state order after the Tanzimat, providing clues about the state's efforts to cope with issues it saw as threats, and taking a picture of the current situation in all Ottoman lands in 1894-1895 through the information provided. The content of the article is limited to the review of the status of statistical science in the world and in the Ottoman Empire in the 19th century, the bureaucratic life of Mehmet Behiç Bey, the clerk of the General
Registry Office of the period who prepared the document, and the evaluation of the data in the document showing the status of the provinces of Mosul, Baghdad and Basra in the period following the introduction of the document, and is interpreted in relation to conjuncture dynamics.

The Barito and Asem-Asem Basins occupy the south-eastern corner of Borneo, and are separated by the Meratus Mountains -an accretionary collision complex that records the suturing of East Java-West Sulawesi to Sundaland in the mid-Cretaceous. The basins contain comparable sedimentary successions of Middle Eocene to Pleistocene age, that suggest they once formed a much larger depocentre prior to the uplift of the Meratus in the Neogene. The uplift had a profound effect on the basin architecture, developing a foredeep along the west side of the emerging mountain front, and creating the present-day hydrocarbon plays of the Barito Basin. Thus, understanding the history of the Meratus uplift not only provides insight into the tectonic evolution of the basins, but also the development of the hydrocarbon system. We present a combination of structural, sedimentological, provenance and satellite data that collectively indicate a piecemeal uplift history of the Meratus. Sedimentology, palaeocurrents and zircon geochronology from sandstones of the Montalat Formation strongly suggest that uplift of the northern part of the Meratus initiated during the Early Miocene -considerably earlier than previously thought. In contrast, reversal of palaeocurrents recorded in the upper part of the Warukin Formation indicates that uplift further south did not occur until the Late Miocene. We suggest this diachronous uplift history was facilitated by a pre-existing NW-trending basement fabric visible from gravity data in the Barito Basin and from NW-trending lineaments that dissect the Meratus. * NPA Satellite Mapping, CGG -UK ** Robertson, CGG -UK. *** Palynova, Ltd

Upper Cretaceous deposits in Medvednica Mt. are composed of coarse-grained conglomerates, sandstones, shales and the pelagic Scaglia Limestones. Such deposits in the wider region possess reservoir potential, not previously studied in Northern Croatia. Modal composition of conglomerates, size and distribution of clasts, porosity and permeability were studied from one new exposure in Medvednica Mt., and the results were compared with previously published data from neighboring successions. Conglomerates are polymictic, clast- to matrix-supported, with clasts and matrix entirely composed of local bedrocks. Porosity varies between 4.98 to 10.89% and permeability from 1.13 to 43.3 mD. Overlying pelagic Scaglia Limestones contain pelagic foraminifera of the latest Santonian to Early Campanian age (83 to 85 Ma). Clasts were eroded from the local hinterland, probably transported to the beach by short-term torrents and deposited along the shelves of the proto-Medvednica Island. Previously pre...

Discovery of petroleum source rocks at surface exposures of the Badenian deposits on the northern slopes of Krn dija Mt. is the fi rst record of petroleum source rocks at outcrop in the Croatian part of the Pannonnian basin. Rocks with increased organic matter content have the characteristics of prime source rocks. Positive hydrocarbon potential is the consequence of a favourable type of organic facies. Type II kerogen is of mostly marine algal origin, but with somewhat more pronounced terrigenic lipid content. Source rocks are in the immature, diagenetic period of thermal transformation. Genesis of these rocks is related to the reducing depositional environment in a mostly shallow sea, formed in protected lagoons during the Badenian period, which was reconstructed using palaeogeomorphological, palaeontological, petrographical and organogeochemical analyses. These new petrological data deserve attention as they highlight the need for additional geological-geophysical-geochemical research of the petroleum potential of the Badenian deposits in the broad area around Našice.