Relevant bibliographies by topics / Geology Mineralogy Petroleum

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Academic literature on the topic 'Geology Mineralogy Petroleum'

Author: Grafiati
Published: 4 June 2021
Last updated: 18 February 2022

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Journal articles on the topic "Geology Mineralogy Petroleum"

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Birdwell, Justin E., Lionel C. Fonteneau, and Brigette A. Martini. "Mineralogy and lithology of the Upper Cretaceous Niobrara Formation determined by hyperspectral core imaging." Mountain Geologist 57, no. 2 (April 1, 2020): 121–43. http://dx.doi.org/10.31582/rmag.mg.57.2.121.

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Sections of the Upper Cretaceous (Coniacian to Campanian) Niobrara Formation in two cores from Kansas and Colorado, the Amoco Rebecca Bounds and USGS Portland 1, respectively, were examined by hyperspectral core imaging and analysis. A spectral imaging system combining high-resolution photography (50 μm), 3D laser profiling (20 μm), and near-visible + short-wave infrared reflectance spectroscopy (wavelengths from 450 to 2500 nm, 500 μm pixel size) was applied to these cores to provide spectral and textural data facilitating creation of continuous mineral and lithology class maps. In addition, compositing of pixel-based results to group pixels to create mineralogical and lithological logs (0.5-ft resolution) was performed to facilitate comparisons to other geochemical datasets. The results show general correspondence in trends identified by previous geochemistry studies, with some exceptions due to instrumental limitations related to low reflectance of some rock intervals and the limited range of infrared wavelengths examined. This study provides a cursory overview of an extensive dataset meant to demonstrate the utility of hyperspectral core scanning to studies of mudrocks in petroleum systems as well as the kinds of information this technique can provide for detailed examination of stratigraphic features in sedimentary systems more generally.
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Willink, Robbert, and Mitch Allison. "Exploring unconventional plays in the Georgina Basin, central Australia: will the real Arthur Creek Formation hot shale please stand up!" APPEA Journal 55, no. 2 (2015): 430. http://dx.doi.org/10.1071/aj14065.

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The search for hydrocarbons in the southern Georgina Basin in central Australia is now focused on assessing the unconventional potential of the Middle Cambrian lower Arthur Creek Formation. Recent regional well correlation studies, supported by a review of nominated type sections and of regional seismic data, and integrating core-based sedimentological, palaeontological, chemostratigraphic, and geochemical information, suggest that the organic rich hot shale at the base of this formation, encountered in wells drilled in the Dulcie Syncline, is not a correlative of the organic rich hot shale encountered in wells drilled in the Toko Syncline. Although similar in lithofacies and mineralogy, the former is significantly older and is more restricted in geographic distribution to an area west of a prominent northwest to southeast trending shear zone in the basement. This interpretation is contrary to correlations presented in recent publications on the geology and resource potential of the southern Georgina Basin by government agencies, various petroleum consultancy firms that have provided estimates of the volumetric potential of the unconventional hydrocarbon resources in the lower Arthur Creek Formation, and several petroleum companies actively exploring in the basin. Any historical inference that simply assumed the lower Arthur Creek Formation hot shale in the Toko domain should be an attractive unconventional target because of the lithological properties of the lower Arthur Creek Formation hot shale observed in the Dulcie domain is not supported by these revised correlations. Pursuit of the basal lower Arthur Creek Formation unconventional play in the Dulcie Syncline and in the Toko Syncline should be done on their respective merits.
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Bozkaya, Ömer, Hüseyin Yalçin, and Hüseyin Kozlu. "Clay mineralogy of the Paleozoic-Lower Mesozoic sedimentary sequence from the northern part of the Arabian Platform, Hazro (Diyarbakır, Southeast Anatolia)." Geologica Carpathica 62, no. 6 (December 1, 2011): 489–500. http://dx.doi.org/10.2478/v10096-011-0035-6.

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Clay mineralogy of the Paleozoic-Lower Mesozoic sedimentary sequence from the northern part of the Arabian Platform, Hazro (Diyarbakır, Southeast Anatolia)The Paleozoic-Lower Mesozoic units in the Diyarbakır-Hazro region consist of sandstone (subarkose, quartz arenite), mudstone, shale, coal, marl, dolomitic marl, limestone (biomicrite, lithobiosparite, biosparite with lithoclast, dololithobiosparite, dolomitic cherty sparite) and dolomite (dolosparite, dolosparite with lithoclast, biodolosparite with glauconite). These units exhibit no slaty cleavage although they are oriented parallel to bedding planes. The sedimentary rocks contain mainly calcite, dolomite, quartz, feldspar, goethite and phyllosilicates (kaolinite, illite-smectite (I-S), illite and glauconite) associated with small amounts of gypsum, jarosite, hematite and gibbsite. The amounts of quartz and feldspar in the Silurian-Devonian units and of dolomite in the Permian-Triassic units increase. Kaolinite is more commonly observed in the Silurian-Devonian and Permian units, whereas illite and I-S are found mostly in the Middle Devonian and Triassic units. Vertical distributions of clay minerals depend on lithological differences rather than diagenetic/metamorphic grade. Authigenetic kaolinites as pseudo-hexagonal bouquets and glauconite and I-S as fine-grained flakes or filaments are more abundantly present in the levels of clastic and carbonate rocks. Illite quantities in R3 and R1 I-S vary between 80 and 95 %. 2M1+1Mdillites/I-S are characterized by moderatebcell values (9.005-9.040, mean 9.020 Å), whereas glauconites have higher values in the range of 9.054-9.072, mean 9.066 Å. KI values of illites (0.72-1.56, mean 1.03 Δ2θ°) show no an important vertical difference. Inorganic (mineral assemblages, KI, polytype) and organic maturation (vitrinite reflection) parameters in the Paleozoic-Triassic units agree with each others in majority that show high-grade diagenesis and catagenesis (light petroleum-wet gas hydrocarbon zone), respectively. The Paleozoic-Triassic sequence in this region was deposited in the environment of a passive continental margin and entirely resembles the Eastern Taurus Para-Autochthon Unit (Geyikdağı Unit) in respect of lithology and diagenetic grade.
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Otoijamun, Itohan, Moses Kigozi, Adelana Rasak Adetunji, and Peter Azikiwe Onwualu. "Characterization and Suitability of Nigerian Barites for Different Industrial Applications." Minerals 11, no. 4 (March 30, 2021): 360. http://dx.doi.org/10.3390/min11040360.

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This work aimed to characterize barite samples from selected different locations in Nigeria and determine their suitability for various industrial applications. The properties determined include mineralogy, chemical composition, morphology, functional groups, and specific gravity. Samples were obtained from ten locations in Nasarawa and Taraba states as well as a standard working sample (WS) obtained from a drilling site. The samples were characterized using scanning electron microscope and energy dispersive X-ray (SEM-EDX), Fourier infrared analysis (FTIR), and X-ray diffraction (XRD). Specific gravity (SG) was determined using the pycnometer method. Results of SEM-EDX analysis show that the WS has a Ba-S-O empirical composition of 66.5% whereas these of the ten samples investigated vary between 59.36% and 98.86%. The FTIR analysis shows that the functional groups of S-O, SO42−, Ba-S-O, OH of the ten samples match that of the WS. Results of XRD show that the ten samples have the same mineralogical composition as the WS and all meet American Petroleum Institute (API) standards for industrial barite. Similar matching results are shown from EDXRF spectra intensity, position, and composition analysis of the ten samples compared to the WS. Specific gravity (SG) results show that six out of the ten samples have SG above 4.2 which is the recommended minimum for the American Petroleum Institute (API) standard. The other four samples will require beneficiation to meet the standard for drilling mud application. Using all the parameters of the assessment together, results show that while some (6) of the samples can be used for drilling fluid application, some (4) require beneficiation but all ten samples can be used for other industrial applications including healthcare, construction, plastic, cosmetics, paper, and rubber industries. The results of the study can be used for value addition in developing beneficiation procedures, processes, and technology for purification along with new materials for the industries.
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Liu, Hui Qing, and Yu Yuan Zhong. "Application of Organic Inclusion in Hydrocarbon Exploration." Advanced Materials Research 424-425 (January 2012): 545–50. http://dx.doi.org/10.4028/www.scientific.net/amr.424-425.545.

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Inclusion as a research method was mainly applied in the study of mineral deposit geology in the beginning. In recent years, organic inclusion research has become one of the important means in hydrocarbon exploration. The study of the inclusion can determine the role of diagenesis and reservoir of time and temperature, infer hydrocarbon migration, tectonic movement and paleo-heat flow history, in order to better guide hydrocarbon exploration. This paper mainly discussed research method of hydrocarbon inclusions type and oil and gas inclusion, and summarizes the inclusion of the fracture structure used to study and hydrocarbon accumulation relations, determines the gas accumulation time, evaluate hydrocarbon, calculate fluid potential, predict oil and gas accumulation zones, and other aspects of the role. Inclusions found early, at first is mainly applied in the study of mineral deposit geology. Since Marray (1957) discovered larger hydrocarbon inclusions in quartz especially[1], in the 70 s, with the development of oil geochemical, the minerals fluid inclusions in the oil field geological research has been widely used. G. m. Gigashvili and v. p. Kalish in 1977 are the first to report the use of mineral inclusions as the hydrocarbons containing hydrocarbon migration of physical and chemical condition of fluid of the index. At the beginning of the 80's, the technology has already been foreign research institutions and oil company are widely used in reservoir the diagenesis of research and oil and gas exploration [2,3,4]. China has begun to set up in the 1960 s, the early main inclusions laboratory to research various metal hydrothermal ore deposits in the ore-forming temperature and the composition of the ore-forming fluid. ShiJiXi (1985,1987) will fluid inclusions method is used to study the carbonate formation of China and the thermal evolution degree, division of hydrocarbon generation evolutionary stages, according to package the body type, distribution, homogenization temperature, salinity, gas organic composition various inclusions observation and analysis data put forward the carbonate hydrocarbon source rocks and oil and gas reservoir has performance evaluation method and hydrocarbon index[2,5,6]. In petroleum exploration, through[[ First Author: Huiqing Liu (1980－), male, doctoral students, Major: mineralogy petrology mineralogy,E-mail:liu8935959@163.com]] the study of the sandstone reservoir formation of diagenetic minerals fluid inclusions, and combining with the chip observation to judge whether have oil and gas migration to reservoir, and oil and gas accumulation of time, ancient geothermal, formation water such as the salinity has a very important significance
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Mylnikova, L. N., L. S. Kobeleva, and M. S. Nesterova. "Multidisciplinary Research of Sites and Materials of the Baraba Forest-Steppe in Holocene: To the 45th Anniversary of the West-Siberian Archaeological Detachment of the SB RAS." Archaeology and Ethnography 17, no. 7 (2018): 18–43. http://dx.doi.org/10.25205/1818-7919-2018-17-7-18-43.

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Purpose. We show the main directions of work of the West Siberian archaeological detachment (team) of the Institute of Archaeology and Ethnography SB RAS, demonstrate the methods used and present the results and the possibilities of their interpretation. Results. In 2018, the West Siberian archaeological detachment celebrates the 45th anniversary of its formation. The long-term head of the team is academician V. I. Molodin. All studies are carried out within the framework of a multidisciplinary approach starting from the search for archaeological objects (sites Tartas-1, Vengerovo-2, -2A, -6, Staryi Tartas-5, Ust’-Tartas-1,-2; Chicha-1, Vengerovo-6 and others) to their laboratory investigation. We widely apply a range of analytical methods in all of our activities including almost all stages of research: from the search for archaeological sites to their processing in close cooperation with various scientists. We collaborate with specialists from the Institute of Geology and Mineralogy SB RAS, Novosibirsk, Russia; the Institute of Petroleum Geology and Geophysics SB RAS, Novosibirsk, Russia; the Institute of Solid State Chemistry and Mechanochemistry SB RAS, Novosibirsk, Russia; the Institute of Cytology and Genetics SB RAS, Novosibirsk, Russia; the Institute of Nuclear Physics SB RAS, Novosibirsk, Russia; Novosibirsk National Research State University, Novosibirsk, Russia; the Center of Collective Use (CCU) “Geochronology of Cenozoic”, Novosibirsk, Russia; Heidelberg University, Heidelberg, Germany; Ludwig-Maximilian Munich Institute, Munich, Germany; the Center of Archaeology of Kurt Engelhorn, Mannheim, Germany and others. Conсlusion. Studies of the West Siberian archaeological detachment, which were carried out over the recent two decades, have provided new data that develop existing points of view, clarify existing concepts or allow to build new concepts of historical and cultural processes. It is obvious that the modern paradigm of science requires participation of specialists in natural sciences at all stages of archaeological research.
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El-Bagoury, Mohamed. "Integrated petrophysical study to validate water saturation from well logs in Bahariya Shaley Sand Reservoirs, case study from Abu Gharadig Basin, Egypt." Journal of Petroleum Exploration and Production Technology 10, no. 8 (August 18, 2020): 3139–55. http://dx.doi.org/10.1007/s13202-020-00969-3.

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Abstract Water saturation is a key parameter in evaluating oil and gas reservoirs and calculating OIIP and GIIP for petroleum fields. The late Cretaceous Bahariya reservoir contains variable amounts of clay minerals. Bore hole logs are affected with those clay minerals particularly the density and resistivity logs. Several methods are acknowledged to determine the true water saturation from well logs in shaley sand reservoirs. Each method assumes a sort of corrections to amount of shale distributed in the reservoir. The scope of this petrophysical study is to integrate core analysis and bore hole logs to investigate the characteristics of water saturation in the Bahariya reservoirs. Comparison between most of the significant shaley sand methods is presented in this research. Reservoir lithology and mineralogy are explained by Elan-model while bore hole images are used for fine-tuning the electrofacies. Siltstone, shaley sand and clean sandstones are the main electrofacies that is characterizing the Bahariya reservoir rocks. For accurate saturation results, some core samples have been used for validating the log-derived water saturation. Dean stark and cation exchange capacity experiments are integrated with bore hole logs to calculate the error in water saturation for each method for best calibration. The successful integration between logs and core measurements led to convenient log evaluation and accurate understanding for the Bahariya reservoir in the prospective part of Abu Gharadig basin.
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Botoucharov, Nikola. "GEOLOGICAL EDUCATION IN SOFIA UNIVERSITY – INTEGRATION OF TRADITIONS AND KNOWLEDGE IN PRACTICE." Knowledge International Journal 28, no. 3 (December 10, 2018): 1093–98. http://dx.doi.org/10.35120/kij28031093n.

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Sofia University “St. Kliment Ohridski” is the first Bulgarian and the highest academic institution with more than a century long educational and scientific traditions. Geology is part of the university from the very beginning in the area of Natural sciences. It is an example of the effective interaction between the educational processes and implementation of science, technology and innovation. The scientific activities of Sofia University have been developing along with the research priorities, lecture courses, field work and their implementation into practice.The degree programs in Geology were set up at the end of the 19th century, just 3 years after foundation of the Sofia University. The first lectures in Geology and Mineralogy dates back to 1891 when the Department for Natural History at the Sofia University started. They both form the basis of education and research in the field of Geology in Bulgaria. The main contribution in the beginning for the development of teaching and research belongs to remarkable scientists like Prof. Georgi Zlatarski, Prof. Georgi Bonchev, Prof. Stefan Bonchev, Prof. Lazar Vankov, Prof. Dimitar Yaranov and so many others. Faculty of Biology, Geology and Geography inherits the Faculty of Natural History, but is later divided.Faculty of Geology and Geography in Sofia University was formed in 1963 and till now the geology is studied in a regular form of education. There are Bachelor, Master and PhD degrees with duration of 8, 3 and 6 semesters respectively. The Bachelor Degree provides fundamental knowledge in all geological disciplines. The Master Degree covers a wide range of educational and scientific research work carried out in specialized, well-equipped laboratories for investigation of geological objects. PhD Degree is a basic form of organized training for highly qualified graduates in all spheres of geological science and practice.The teaching process in the Faculty focuses on the lectures and seminars, as well as on the individual forms of education – tasks, course and diploma thesis works, laboratory and field practices. The educational practices - stationary and field trips to certain geological, mining or economic sites are regularly held after the end of the summer semesters. Modern profile of Geology means that students obtain detailed knowledge on structure, tectonics, geological features, underground and surface processes of the Earth as well as regularities for the accumulation and distribution of ores, non-metalliferous raw materials, coal, oil and gas.The implementation of geological education into practice is supported by student membership in various society and sections. The specific activities focus student interests in organized working groups, participation in field trips and applied research. These non-profit organizations integrate in the best way geological traditions from the industry and knowledge from university into the future career development of young people. The Sofia University SEG Student Chapter supports student field trips with the idea to provide understanding of main geological characteristics of the visited geological sites and obtain specific skills of investigation and mining exploration. The Sofia University Student Chapter of AAPG actively contributes to student community growth, enriching educational culture and expanding geological expertise of its members in the field of Petroleum geology.
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Teklu, Tadesse Weldu, Xiaopeng Li, Zhou Zhou, and Hazim Abass. "Experimental Investigation on Permeability and Porosity Hysteresis of Tight Formations." SPE Journal 23, no. 03 (October 4, 2017): 672–90. http://dx.doi.org/10.2118/180226-pa.

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Summary The decrease of permeability and porosity with increasing net stress in consolidated and unconsolidated porous media is a well-known phenomenon to petroleum and geomechanics engineers. Conversely, permeability and porosity are observed to increase when net stress decreases; however, they typically follow a different path; this discrepancy is known as hysteresis. The trend of permeability and porosity hysteresis is a signature of porous media that depends on several chemical, physical, and mechanical properties. Understanding permeability and porosity hysteresis plays a significant role in production strategies of hydrocarbon reservoirs. The hysteresis effect on production strategies can be even more important in very-low-permeability reservoirs such as tight sandstone, tight carbonate, and shale/mudstone formations. The reason is that the stress change associated with permeability and porosity hysteresis can affect adsorption/desorption and diffusion-transport mechanisms that are among the main driving mechanisms in low- or ultralow-permeability reservoirs. In this study, matrix permeability and porosity hysteresis of nano-, micro-, and millidarcy core samples are measured for a wide range of net stresses (500 to 4,500 psia). The matrix includes nano- and micrometer-sized cracks (fractures) that are open or mineral-filled (sealed) cracks. The nano- and microdarcy core samples are from the Niobrara, Bakken, Three Forks, and Eagle Ford formations. The millidarcy core samples are from Middle East carbonate, Indiana Limestone, and Torrey Buff Sandstone formations. Bakken, Three Forks, and Middle East carbonate core samples are from oil-producing reservoirs, whereas others are from outcrop. The major experimental observations of this study are that (a) the stress dependency and hysteresis of permeability and porosity were observed to be larger for nanodarcy cores compared with those of microdarcy and millidarcy core samples; (b) stress dependency and hysteresis of porosity are smaller than those of permeability; (c) pore shape, pore size and their distributions, and mineralogy affect the stress dependency and hysteresis of both permeability and porosity; and (d) increase in permeability with increasing temperature and permeability hysteresis through temperature loading and unloading were observed in organic-rich core sample from Eagle Ford.
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Gupta, Ishank, Ngoc Tran, Deepak Devegowda, Vikram Jayaram, Chandra Rai, Carl Sondergeld, and Hamidreza Karami. "Looking Ahead of the Bit Using Surface Drilling and Petrophysical Data: Machine-Learning-Based Real-Time Geosteering in Volve Field." SPE Journal 25, no. 02 (January 10, 2020): 990–1006. http://dx.doi.org/10.2118/199882-pa.

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Summary Petroleum reservoirs are often associated with multiple target zones or a single zone adjacent to nonproductive intervals. Real-time geosteering therefore becomes important to remain in zone or to dynamically steer toward a target. This requires knowledge of the petrophysical/rock mechanical properties of the rock surrounding the bit. Although logging while drilling can provide this information, a cost-effective and almost-real-time solution is lacking. In general, there is a depth lag, and therefore, a time delay, between what the logging-while-drilling sub relays to the surface and the bit performance. This study focuses on relating drill-bit- and drillstring-performance data in a machine-learning (ML) workflow to predict the lithology at the bit while drilling. The method we are proposing offers several advantages in terms of cost and time savings for real-time geosteering applications, where going out of zone requires costly intervention. In this study, we have used a public data set from Volve Field on the Norwegian continental shelf. Within our proposed workflow, as a first step, logs sensitive to lithology [such as density, gamma ray (GR), and sonic] are grouped into three electrofacies. We also had access to core data, which helped us interpret the electrofacies in terms of mineralogy. The three electrofacies corresponded to quartz-rich (sandstone/siltstone), clay-rich (shale), and carbonate-rich (limestone) lithologies. The next step is to predict the electrofacies using various measurement-while-drilling (MWD) variables, such as rate of penetration (ROP), weight on bit (WOB), and several others that are monitored in real time. Supervised classification algorithms were used to relate real-time surface measurements to lithology. The algorithms were able to predict lithology in test wells with more than 80% accuracy. These results, although encouraging, constitute a small step toward drilling-automation/advisory systems. The development of such systems can prevent costly out-of-zone drilling and minimize rig time and equipment use, thereby potentially reducing capital expenditures. This study was specifically performed in Volve Field in the North Sea using petrophysical and surface drilling data from vertical wells. However, the workflow has a potential to be extended to other formations in other fields in different well types.
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Dissertations / Theses on the topic "Geology Mineralogy Petroleum"

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Chatterton, Logan. "Spectral analysis of petroleum reservoir rock using fourier transform infrared (FTIR) spectroscopy." Thesis, Oklahoma State University, 2016. http://pqdtopen.proquest.com/#viewpdf?dispub=10140532.

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Compositional analysis of reservoir rock is a vital aspect of oil exploration and production activities. In a broad sense, knowing the mineral composition of a reservoir can help with characterization and interpretation of depositional environments. On a smaller scale, identifying mineralogy helps calibrate well logs, identify formations, design drilling and completion programs, and screen for intervals with potential problem minerals, such as swelling clays. The petroleum industry utilizes two main methods to find compositional mineralogy, x-ray diffraction (XRD) and thin section analysis. Both methods are time consuming, expensive, and destructive. An alternative method for compositional analysis that includes quantitative mineralogy is a valuable prospect, especially if it had the potential to characterize the total organic content (TOC).

The remote sensing community has been using infrared spectroscopy to analyze mineralogy for years. Within the last ten years, the advancement of infrared spectrometers and processing programs have allowed infrared spectra to be taken and analyzed faster and easier than before. The objective of this study is to apply techniques used in remote sensing for quantitatively finding mineralogy to the petroleum industry. While developing a new methodology to compositionally analyze reservoir rock, a database of infrared spectra of relevant minerals has been compiled. This database was used to unmix spectra using a constrained linear least-squares algorithm that is used in the remote sensing community. A core has been scanned using a hand-held infrared spectrometer. Results of the best method show RMS error from mineral abundance to be under five percent.

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Calleja, Glecy School of Biological Earth &amp Environmental Sciences UNSW. "Influence of mineralogy on petrophysical properties of petroleum reservoir beds." Awarded by:University of New South Wales. School of Biological, Earth and Environmental Sciences, 2005. http://handle.unsw.edu.au/1959.4/22423.

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Key petrophysical properties of reservoir sequences are determined by their individual mineral compositions, and are routinely evaluated through the analysis of cores and geophysical well logs. However, mineralogical studies are seldom incorporated in reservoir assessment. The objectives of the study were to investigate the influence of mineralogy on petrophysical properties of petroleum reservoir beds and the application of mineralogical studies in reservoir evaluation. Mineralogical analyses were performed on core samples from the Plover Formation, the principal reservoir sequence in the Northwest Shelf area of Australia, intersected in two separate wells in the Laminaria petroleum field. The techniques used included X-ray powder and oriented-aggregate analysis, optical microscopy and whole rock geochemistry. Quantification of each mineral phase based on whole-rock powder data was performed using the Rietveld-based Siroquant technique. Results from the Siroquant assay were used as an indicator of mineralogy for the individual samples and were compared with core plug and geophysical log data. X-ray micro-tomography analysis of selected samples was also performed. The reservoir sequences in both wells were sand-dominated, consisted mostly of quartz, clay mineral matrix and cement of silica, pyrite or calcite. The abundance of clay minerals increased in the shale and shaly sandstone intervals. Comparison of mineralogical and core plug analyses of samples from the same depths showed that the down-hole variations in porosity, permeability, grain density and radioactivity were accompanied by changes in mineralogy. Higher proportion of clay minerals in shales was indicated by higher gamma log signals. The gamma log may be taken as an indicator of shaliness only in intervals where kaolinite is proportional to the quantity of illitic clays. Sonic log and neutron log porosity values are comparable with core plug porosity data in sandstone intervals. However, clay minerals increase the sonic log response, thereby increasing porosity in shaly intervals. Clay minerals tend to decrease the neutron log response causing higher porosity indication in shales, similar to that expected in sandstones. Routine density log analysis underestimated porosity values because of the contribution of dense minerals to the bulk density of the formation. Use of laboratory determined grain and fluid densities resulted in improved density log porosity compared to core porosity. X-ray tomography analysis revealed an overall positive correlation between mineralogy and porosity data. Routine geophysical log evaluation revealed inconsistent results when compared to core analysis data because of the influence of minerals on various logs. It is essential that mineralogical studies be included in reservoir assessment. X-ray tomography may provide an alternative approach in evaluating porosity and mineralogy.
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Ring, Jeremy Daniel. "Petrophysical evaluation of lithology and mineral distribution with an emphasis on feldspars and clays, middle and upper Williams Fork Formation, Grand Valley Field, Piceance Basin, Colorado." Thesis, University of Colorado at Boulder, 2014. http://pqdtopen.proquest.com/#viewpdf?dispub=1565317.

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Petrophysical evaluation of lithology and mineral distribution with an emphasis on feldspars and clays, middle and upper Williams Fork Formations, Piceance Basin, Colorado. Understanding accessory mineralogy occurrence and distribution is critical to evaluating the reservoir quality and economic success of tight–gas reservoirs, since the occurrence of iron–rich chlorites can decrease resistivity measurements and the occurrence of potassium feldspar increases gamma–ray measurements, resulting in inaccurate water saturation and net–to–gross calculations, respectively. This study was undertaken to understand the occurrence and distribution of chlorite and potassium feldspar in the middle and upper Williams Fork Formations of the Piceance Basin at Grand Valley Field.

Eight lithofacies are identified in core based on grain–size, internal geometry, and sedimentary structures. Four architectural elements (channel fill, crevasse splay, floodplain, and coal) were determined from lithofacies relationships, and then associated with well–log responses. Logs and models were used to determine the occurrence and distribution of lithology, architectural elements, chlorite and potassium feldspar, as well as the relationships between minerals and lithology and architectural elements. Net–to–gross ratios vary stratigraphically, from 8% to 88%, with a higher average in the middle Williams Fork Formation (58.3%) than in the upper Williams Fork Formation (48.5%). Volumetric proportions vary stratigraphically for both channel fills (18– 75%) and crevasse splays (1–7%).

The average volume percent of chlorite and potassium feldspars are both <1%, with P 50 values of 1.3% and 7%, respectively. Chlorite is pervasive at the base of the middle Williams Fork Formation: almost 90% of the sandstones in sand–rich intervals contain chlorite. The distribution of chlorite did not vary between reservoir architectural elements, with 70% of both crevasse splays and channel fills containing chlorite. The results of this study show that, for the middle and upper Williams Fork Formations at Grand Valley Field, 1) there are eight lithofacies and four architectural–element types identified from core; 2) the occurrence and distribution of accessory minerals (<10%) of chlorite and potassium feldspar can be accurately estimated from limited core and well–log data; 3) chlorite occurrence does not vary significantly between reservoir architectural elements; 4) the abundance of chlorite near completion intervals and the occurrence of potassium feldspar in calculated mudstone lithologies indicate a need to re–evaluate the utilization of saturation models and lithology calculations in reservoir–quality evaluations.

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Lowry, Robert Michael. "Origin and Evolution of Brines from the "Clinton" Sandstone, Eastern Ohio, Using Variations in Geochemical and Isotopic Data, with Applications to Petroleum Migration." The Ohio State University, 1986. http://rave.ohiolink.edu/etdc/view?acc_num=osu1392378799.

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Kurtz, Aaron D. "Determining Mineralogy from Traditional Well Log Data." Marietta College Honors Theses / OhioLINK, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=marhonors1366902854.

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Foley, Derek J. "Analysis of the Point Pleasant/Lexington/Trenton Formations: Sulfides, Mineralogy, and Trace Elements as Geochemical Proxies." The Ohio State University, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=osu1461333436.

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Gibbs, Eric W. "Petrographic, Geochemical, and Geophysical Well Log Assessment of the PrecambrianBasement in Eastern Ohio." Ohio University / OhioLINK, 2020. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1596650575249807.

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Lichtfouse, Eric. "Fossiles moléculaires d'intérêt microbiologique, pétrolier, agronomique et environnemental." Habilitation à diriger des recherches, Institut National Polytechnique de Lorraine - INPL, 1998. http://tel.archives-ouvertes.fr/tel-00173971.

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Les fossiles moléculaires sont de puissants outils pour étudier l'origine, la transformation et le transfert de la matière organique dans les écosystèmes modernes et anciens. Marqueurs d'origine, ils livrent des informations sur le milieu de dépôt, en précisant notamment les sources de la matière organique et la place de leur précurseurs biologiques dans les chaînes alimentaires. De manière surprenante, la découverte de certains fossiles "orphelins" peut conduire à l'identification de nouvelles substances biologiques. L'analyse isotopique de marqueurs végétaux des sols permet d'étudier la dynamique de l'humus au niveau moléculaire. Marqueurs de processus, leur structure et leur composition isotopique révèlent la nature des réactions géochimiques opérant dans les milieux très complexes tels les sols et les sédiments. Marqueurs de maturité, les fossiles moléculaires mesurent l'intensité du stress thermique subi par la matière organique au cours de l'enfouissement dans les sédiments. À cet égard, ils s'avèrent utiles à la fois pour la recherche pétrolière et pour authentifier la présence de contamination pétrolière dans les écosystèmes modernes. Ainsi, le concept de marqueur moléculaire développé en géochimie pétrolière est à la base d'un domaine scientifique en émergence, la géochimie organique environnementale.
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Books on the topic "Geology Mineralogy Petroleum"

1

Poppe, Lawrence J. Lithology and X-ray mineralogy of the Shell 410-1 well, U.S. North Atlantic Outer Continental Shelf. Woods Hole, MA: U.S. Geological Survey, 1995.

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2

Moore, Clyde H. Carbonate reservoirs: Porosity evolution and diagenesis in a sequence stratigraphic framework. Amsterdam: Elsevier, 2001.

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Yuchuan, Chen, ed. Di 30 jie guo ji di zhi da hui lun wen ji: Zhong wen ban. Beijing: Di zhi chu ban she, 1999.

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Proceedings of the 30th International Geological Congress: Beijing, China, 4-14 August 1996. Utrecht, Netherlands: VSP, 1997.

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Yuchuan, Chen, ed. Di 30 jie guo ji di zhi da hui lun wen ji. Beijing: Di zhi chu ban she, 1999.

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Glikson, M. Organic Matter and Mineralisation: Thermal Alteration, Hydrocarbon Generation and Role in Metallogenesis. Springer Netherlands, 2010.

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(Editor), Huang Yunhui, and Cao Yawen (Editor), eds. Mineralogy: Proceedings of the 30th International Geological Congress. Brill Academic Publishers, 1997.

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Geodynamics and Minerageny of Kazakhstan. VAC Publishing House, 2000.

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1923-, Hosterman John W., ed. Chemistry and mineralogy of natural bitumens and heavy oils and their reservoir rocks from the United States, Canada, Trinidad and Tobago, and Venezuela. [Washington, D.C.]: U.S. G.P.O., 1990.

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Carbonate Reservoirs: Porosity and Diagenesis in a Sequence Stratigraphic Framework. Elsevier Science & Technology Books, 2013.

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