Relevant bibliographies by topics / Reservoir geology

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Reservoir geology'

Author: Grafiati
Published: 4 June 2021
Last updated: 12 February 2022

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Journal articles on the topic "Reservoir geology"

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Meng, Ning Ning, Guang Xue Zhang, Gao Qun Wei, and Xin Lv. "Study on Three-Dimensional Geological Modeling of Reservoir in Hei46 Block." Advanced Materials Research 1073-1076 (December 2014): 2349–52. http://dx.doi.org/10.4028/www.scientific.net/amr.1073-1076.2349.

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Three dimensional (3D) geologic modeling is used to study the reservoir quantitatively from a three-dimensional angle, and its core is the prediction to reservoir of multi-disciplinary integration, quantitative and visualization. Compared with traditional reservoir research, it has a significant advantage. This paper makes geological modeling research and builds structural models sedimentary micro-facies models and phased property model for Hei46 block of Daqingzi oilfield by utilizing 3D geologic modeling technique and petrel software on the basis of integrated using of geology, logging, oil production test, production of dynamic information, thus it provide a reliable basis for reservoir's development and adjustment.
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Yu, Jiang Tao, Jin Liang Zhang, and Shuang Yan Chen. "Application of Three-Dimensional Fine Geological Modeling in Complex Fault-Block Reservoir with Low Permeability." Applied Mechanics and Materials 511-512 (February 2014): 779–82. http://dx.doi.org/10.4028/www.scientific.net/amm.511-512.779.

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Three dimensional geologic modeling is a powerful tool for reservoir development stages of geological study, it can solves many traditional problems existing in geological research through the establishment of precise three dimensional geologic modeling and represents an important direction for the further development of oilfield geological research. Low permeability and thin interbed reservoir of complex fault block have the characteristics of severe heterogeneity, complex relations of oil-water distribution, poor development effect, it is necessary to built high precision three dimensional geologic modeling in the process of oilfield exploration and to fine reservoir description and prediction on this basis, finally reach the purpose of reduce the risk of development and improve the economic benefit. This paper makes geological modeling research and builds structural models sedimentary micro-facies models and phased property model for Zhuzhuang block of Jiangsu oilfield by utilizing three dimensional geologic modeling technique and petrel geology modeling software on the basis of integrated using of geology, logging, oil production test, production of dynamic information, thus it provide a solid basis for reservoir's development and adjustment.
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Mayall, Michael. "Advances in reservoir geology." Marine and Petroleum Geology 11, no. 3 (June 1994): 412. http://dx.doi.org/10.1016/0264-8172(94)90059-0.

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Burchette, Trevor. "Advances in reservoir geology." Sedimentary Geology 88, no. 3-4 (January 1994): 311–13. http://dx.doi.org/10.1016/0037-0738(94)90073-6.

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Chapman, Richard E. "Advances in reservoir geology." Earth-Science Reviews 34, no. 4 (August 1993): 282–83. http://dx.doi.org/10.1016/0012-8252(93)90068-i.

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Hoffman, Monty, and James Crafton. "Multiphase flow in oil and gas reservoirs." Mountain Geologist 54, no. 1 (January 2017): 5–14. http://dx.doi.org/10.31582/rmag.mg.54.1.5.

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The porous rocks that make up oil and gas reservoirs are composed of complex combinations of pores, pore throats, and fractures. Pore networks are groups of these void spaces that are connected by pathways that have the same fluid entry pressures. Any fluid movement in pore networks will be along the pathways that require the minimum energy expenditure. After emplacement of hydrocarbons in a reservoir, fluid saturations, capillary pressure, and energy are in equilibrium, a significant amount of the reservoir energy is stored at the interface between the fluids. Any mechanism that changes the pressure, volume, chemistry, or temperature of the fluids in the reservoir results in a state of energy non-equilibrium. Existing reservoir engineering equations do not address this non-equilibrium condition, but rather assume that all reservoirs are in equilibrium. The assumption of equilibrium results in incorrect descriptions of fluid flow in energy non-equilibrium reservoirs. This, coupled with the fact that drilling-induced permeability damage is common in these reservoirs, often results in incorrect conclusions regarding the potential producibility of the well. Relative permeability damage, damage that can change which fluids are produced from a hydrocarbon reservoir, can occur even in very permeable reservoirs. Use of dependent variables in reservoir analysis does not correctly describe the physics of fluid flow in the reservoir and will lead to potentially incorrect answers regarding producibility of the reservoir.
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Zhang, Xuejuan, Lei Zhang, Dandan Wang, Kuo Lan, Xuesong Zhou, Hongyu Yu, Ruhao Liu, and Xueying Lv. "Nonuniform grid upscaling method for geologic model of oil reservoir: A case study of the W block in the northern part of the Songliao Basin." Interpretation 9, no. 2 (April 7, 2021): T443—T452. http://dx.doi.org/10.1190/int-2020-0112.1.

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At present, uniform upscaling division methods are routinely used to upscale geologic model grids, resulting in overly fine grids in some areas of the model. To improve computational efficiency, we have examined the effect of model upscaling with different upscaling parameters with the goal of producing a nonuniform grid with uniform accuracy. We based our nonuniform upscaling grid method on geologic characteristics including reservoir thickness, physical properties, reservoir spacing, and water flooding. Most of the logging curves of thin reservoirs are finger-like, allowing us to define the grid size according to the reservoir thickness. We use two different strategies to discretize uniform and composite reservoirs and represent reservoir thickness that exhibit bell- and funnel-shaped logging curves. Although one grid point accurately represents a uniform reservoir, we find that composite reservoirs require four or five points to accurately represent the physical properties of a composite reservoir. For the thick reservoirs (>5 m) with box- or composite-type logging curves, the physical properties inside the reservoir do not change much; therefore, we use a grid point to represent the reservoir thickness information. Using these metrics, we constructed alternative “moderate” and “efficient” vertical grid upscaling strategies. Taking the 15 sedimentary units with a total thickness of 72 m as an example, the statistical results show that the computational efficiency using our data-adaptive grid can be increased more than five times compared to the traditional uniform fine-grid method while retaining the same accuracy.
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Ahmed, Rayan. "Geological Model for Mauddud Reservoir Khabaz Oil Field." Iraqi Geological Journal 54, no. 1D (April 30, 2021): 29–42. http://dx.doi.org/10.46717/igj.54.1d.3ms-2021-04-23.

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The Mauddud reservoir, Khabaz oil field which is considered one of the main carbonate reservoirs in the north of Iraq. Recognizing carbonate reservoirs represents challenges to engineers because reservoirs almost tend to be tight and overall heterogeneous. The current study concerns with geological modeling of the reservoir is an oil-bearing with the original gas cap. The geological model is establishing for the reservoir by identifying the facies and evaluating the petrophysical properties of this complex reservoir, and calculate the amount of hydrocarbon. When completed the processing of data by IP interactive petrophysics software, and the permeability of a reservoir was calculated using the concept of hydraulic units then, there are three basic steps to construct the geological model, starts with creating a structural, facies and property models. The reservoirs were divided into four zones depending on the variation of petrophysical properties (porosity and permeability). Nine wells that penetrate the Cretaceous Formation (Mauddud reservoir) are included to construct the geological model. Zone number three characterized as the most important due to it Is large thickness which is about 108 m and good petrophysical properties are about 13%, 55 md, 41% and 38% for porosity, permeability, water saturation and net to gross respectively. The initial oil and gas in place are evaluated to be about 981×106 STB and 400×109 SCF.
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Larter, S. R., A. C. Aplin, P. W. M. Corbett, Neil Ementon, Mei Chen, and P. N. Taylor. "Reservoir Geochemistry: A Link Between Reservoir Geology and Engineering?" SPE Reservoir Engineering 12, no. 01 (February 1, 1997): 12–17. http://dx.doi.org/10.2118/28849-pa.

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Hussein, Marwa, Robert R. Stewart, Deborah Sacrey, Jonny Wu, and Rajas Athale. "Unsupervised machine learning using 3D seismic data applied to reservoir evaluation and rock type identification." Interpretation 9, no. 2 (April 21, 2021): T549—T568. http://dx.doi.org/10.1190/int-2020-0108.1.

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Net reservoir discrimination and rock type identification play vital roles in determining reservoir quality, distribution, and identification of stratigraphic baffles for optimizing drilling plans and economic petroleum recovery. Although it is challenging to discriminate small changes in reservoir properties or identify thin stratigraphic barriers below seismic resolution from conventional seismic amplitude data, we have found that seismic attributes aid in defining the reservoir architecture, properties, and stratigraphic baffles. However, analyzing numerous individual attributes is a time-consuming process and may have limitations for revealing small petrophysical changes within a reservoir. Using the Maui 3D seismic data acquired in offshore Taranaki Basin, New Zealand, we generate typical instantaneous and spectral decomposition seismic attributes that are sensitive to lithologic variations and changes in reservoir properties. Using the most common petrophysical and rock typing classification methods, the rock quality and heterogeneity of the C1 Sand reservoir are studied for four wells located within the 3D seismic volume. We find that integrating the geologic content of a combination of eight spectral instantaneous attribute volumes using an unsupervised machine-learning algorithm (self-organizing maps [SOMs]) results in a classification volume that can highlight reservoir distribution and identify stratigraphic baffles by correlating the SOM clusters with discrete net reservoir and flow-unit logs. We find that SOM classification of natural clusters of multiattribute samples in the attribute space is sensitive to subtle changes within the reservoir’s petrophysical properties. We find that SOM clusters appear to be more sensitive to porosity variations compared with lithologic changes within the reservoir. Thus, this method helps us to understand reservoir quality and heterogeneity in addition to illuminating thin reservoirs and stratigraphic baffles.
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Dissertations / Theses on the topic "Reservoir geology"

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Marquez, C. Xiomara M. (Marquez Ceballos). "Reservoir geology of upper Devonian Leduc buildups, deep Alberta basin." Thesis, McGill University, 1994. http://digitool.Library.McGill.CA:80/R/?func=dbin-jump-full&object_id=28487.

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Upper Devonian (Frasnian) stromatoporoid and coral buildups in the Alberta Basin are among the most important hydrocarbon reservoirs in Western Canada. In the deep basin ($>$4000 m), Strachan, Ricinus West and adjacent buildups have similar depositional facies, but have experienced different diagenetic processes that affected their reservoir characteristics. The most important diagenetic alteration is dolomitization that partially to completely replaced the original limestone buildups. Replacement dolomitization occurred at shallow depths near 500 m, indicated by petrographic and geologic relationships. The dolomitizing fluid was probably modified Upper Devonian seawater, as suggested by trace element concentrations and $ sp{87}$Sr/$ sp{86}$Sr ratios (0.7083 to 0.7092). These replacement dolomites have similar petrography and geochemical signatures as those in buildups along the Rimbey Meadowbrook reef trend. The presence of similar replacement dolomites over such a broad extent suggests that they formed from similar fluids during a regional to basin-wide event.
Distribution of pore types is controlled by depositional facies, whereas permeability is controlled by diagenetic processes, especially dolomitization. At depths $>$4000 m dolostones have higher porosities and permeabilities than limestones because the dolostones are more resistant to pressure solution. Bitumen is observed to decrease permeability in the upper part of the reservoirs. Later thermal sulphate reduction (TSR) related products both increased and decreased porosity and permeability in the lower part of the reservoirs.
Major differences in diagenesis between the partially dolomitized Strachan buildup (hairline microfracturing) and the completely dolomitized Ricinus West and adjacent buildups likely resulted from the completely dolomitized buildups being connected to a regional fluid conduit system along the west margin of the Cooking Lake platform underlying the Rimbey Meadowbrook reef trend.
Hairline microfractures filled with bitumen are abundant in the Strachan buildup. Subhorizontally, randomly and radially oriented microfractures crosscut all sedimentary and diagenetic phases. Overpressuring caused by the thermal cracking of crude oil to gas during burial and Laramide compression best explains their origin and distribution.
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Monn, Will D. "A multidisciplinary approach to reservoir characterization of the coastal Entrada erg-margin gas play, Utah." Diss., CLICK HERE for online access, 2006. http://contentdm.lib.byu.edu/ETD/image/etd1211.pdf.

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Stewart, Mike. "The geology of the Cobb Reservoir Area, North West Nelson." Thesis, University of Canterbury. Geology, 1988. http://hdl.handle.net/10092/6383.

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This thesis examines the geology of an 80 km2 area of Lower Paleozoic rocks centred on the Cobb Reservoir, N.W. Nelson. An extensive and detailed field mapping programme has identified three fault bounded slices, of markedly contrasting lithologic and deformational character, from west to east the Balloon, Junction and Mataki Fault Bounded Slices. The Balloon Slice comprises predominantly a pervasively foliated, east dipping "block in matrix" tectonite, with lenses of chert, limestone, conglomerate and andesite (collectively known as the Balloon Formation). The tectonite has a strong linear fabric plunging down dip parallel to a regional lineation. Hornblende andesites of calc-alkaline arc affinity are restricted to the Balloon Formation. Conglomerates outcropping north of the Reservoir (the Battey Conglomerate) are of uncertain affinity to the Balloon Formation The Mataki Slice is poorly exposed and understood. It contains three lithologic units of unknown interrelationship; the Salisbury Conglomerate, the M Creek Formation and the Mataki Basalts. The M Creek Formation comprises laminated siltstones and angular basalt rich mass flow conglomerates. The Mataki Basalts are distinctive high Ti and Mg tholeiitic basalts and have a probable seamount trace element signature. The Mataki Slice is bounded to the west by the Mataki Fault and to the east by the Junction Fault. The Junction Slice comprises well bedded quartzose sandstones and siltstones (the Junction Formation), folded into irregularly oriented but consistently east plunging asymmetric folds. Large lateral displacement between the Slices is indicated from the presence of igneous rocks of widely contrasting geotectonic origin. The timing of juxtaposition predates the imposition of a regional extensional deformation, interpreted to be related to the Devonian or Silurian Tuhuan event. It is apparent that the structural complexity of the study area is greater than can be fully resolved with the outcrop available. Previous attempts (Grindley 1971, 1980) to establish a regional stratigraphy are not applicable in this area.
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Evans, Peter Francis. "Sedimentology and reservoir modelling of transitional aeolian/sabkha sequences in Lower Permian (Rotliegend) gas reservoirs of the southern North Sea." Thesis, Keele University, 1989. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.302748.

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Han, Tongcheng. "Joint elastic-electrical properties of reservoir sandstones." Thesis, University of Southampton, 2010. https://eprints.soton.ac.uk/195017/.

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Over the last decade, marine controlled source electromagnetic (CSEM), sub-seabed imaging has developed to a state where routine resistivity mapping of hydrocarbon reservoirs is now possible. Co-located marine seismic and electrical resistivity survey data could provide the engineering parameters needed to better assess the economic potential of hydrocarbon reservoirs without the need for drilling, and could provide additional reservoir monitoring capabilities in the future. However, proper exploitation of joint seismic-CSEM datasets will require a much better understanding of the inter-relationships among geophysical (elastic and electrical) and reservoir engineering properties. This project seeks to study the inter-relationships among the elastic and electrical properties of typical reservoir sandstones for improved insight into wave propagation phenomena in porous rocks. A high quality joint elastic-electrical dataset has been collected on a set of 67 sandstone samples showing a range of porosities, permeabilities and clay contents. The measurements were simultaneously carried out at differential pressures up to 60 MPa. Elastic properties (compressional and shear wave velocity and attenuation) were measured using a pulse-echo technique; electrical resistivity was recorded at AC frequency of 2 Hz using a circumference resistivity measurement method. The effects of porosity, permeability, clay content and differential pressure on the low frequency (2 Hz) electrical resistivity properties and the influence of differential pressure and petrophysical parameters on the joint elastic-electrical properties of reservoir sandstones were analyzed. A three-phase (quartz, brine and pore-filling clay) effective medium model based on self-consistent approximation (SCA) and differential effective medium (DEM) for the joint elastic-electrical properties of reservoir sandstones was developed and was found to give a good description of the experimental observations.
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Malik, Qamar Mehboob. "Electrical and transport properties of sedimentary reservoir rocks." Thesis, Imperial College London, 1997. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.266398.

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Dada, Olamide. "Reservoir Characterization of the Spraberry Formation, Borden County, West Texas." Thesis, University of Louisiana at Lafayette, 2014. http://pqdtopen.proquest.com/#viewpdf?dispub=1557545.

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The Spraberry Formation is a Leonardian age submarine fan deposit restricted to the Midland Basin. The formation consists of very fine-grained sandstone, medium to coarse grain size siltstones, organic shales and carbonate mudstones. These rocks show variability in sedimentary structures and bedding types varied from thinly laminated to convolute laminations. Bioturbations were present in some samples and soft sediment deformation, such as water escape features, sediment loading and flame structures.

The Spraberry Formation is a naturally fractured reservoir with low porosity and low matrix permeability. Porosity measured varied from 2% in rocks with poor reservoir quality such as the argillaceous siltstone and mudstone while good reservoir rocks had an average porosity of 9%. Seven lithofacies were identified based on sedimentary structures, grain size and rock fabrics. Petrographic analysis showed four porosity types: (1) intragraular porosity; (2) dissolution porosity; (3) fracture porosity and (4) intergranular porosity. Fractured porosity was only observed in the argillaceous siltstone lithofacies.

The prominent diagenetic influences on the Spraberry Formation are: quartz cementation, quartz overgrowth, illtization of smectite, feldspar dissolution, clay precipitation, carbonate cementation, formation of framboidal pyrite and fracture formation. These diagenetic features were observed using scanning electron microscope (SEM) and in thin sections. Generally, petrophysical properties, such as porosity and permeability, vary gradually from reservoir rocks to non-reservoir rock. Observed trends where: 1) increasing organic and argillaceous content with decreasing porosity and 2) increasing carbonate sediments and calcite cements with decreasing porosity. Mineralogical analysis from FTIR showed an abundance of quartz and calcite, while illite is the prominent clay mineral observed in all samples.

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Love, Susan Elizabeth. "Floodbasin deposits as indicators of sandbody geometry and reservoir architecture." Thesis, University of Aberdeen, 1993. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=128352.

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Palaeosol development is controlled by topography, drainage, substrate, climate and time. The types and maturities of soil developing within fluvial systems are also controlled by avulsion and terracing. Soil forming models relate variations in pedogenic maturity and morphology to these processes. The pedofacies model and pedofacies sequences apply to lateral and vertical packages deposited under aggradational conditions while the chronosequence model applies across floodplain terraces. The Upper Triassic, Upper Petrified Forest Member, Arizona contains fluvial channel sandstones encased in thick mudstones. Differences in palaeosol development were produced by variations in sedimentation rate, terracing and drainage conditions. The pedofacies and chronosequence models apply to these palaeosols. The Owl Rock member was deposited in lacustrine and lacustrine margin environments. Soil forming models were not recognised here because pedogenic horizons were subject to intense burrowing and reworking by advancing lacustrine margins. Continued basin subsidence and decreasing sediment supply caused the change in depositional environments between the two Members. The Upper Silurian, Old Red Sandstone, Dyfed comprises thick fluvial deposits and numerous stacked palaeosols. Fluvial architecture and palaeosol development was controlled by avulsion, phases of erosion and influxes of volcanic ash. Channel morphologies were broad and sheet-like. Soil morphology and structure reveals complex cycles of varying aggradation and erosion within the sediments. Palaeosols contain variations in maturity consistent with the pedofacies relationship and pedofacies sequences. Upper Triassic to Lower Jurassic Lunde and Statfjord Formations, Snorre Field, North Sea comprise fluvial channels which change from isolated ribbons encased in thick mudstones to laterally extensive channels and palaeosol development decreases from moderate to poor. Regional changes in climate and basin configuration controlled the evolution of the fluvial regime and patterns of pedogenic maturity were not apparent.
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Schepers, Karine Chrystel. "Quantification of uncertainty in reservoir simulations influenced by varying input geological parameters, Maria Reservoir, CaHu Field." Thesis, Texas A&M University, 2003. http://hdl.handle.net/1969.1/1302.

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Finding and developing oil and gas resources requires accurate geological information with which to formulate strategies for exploration and exploitation ventures. When data are scarce, statistical procedures are sometimes substituted to compensate for the lack of information about reservoir properties. The most modern methods incorporate geostatistics. Even the best geostatistical methods yield results with varying degrees of uncertainty in their solutions. Geological information is, by its nature, spatially limited and the geoscientist is handicapped in determining appropriate values for various geological parameters that affect the final reservoir model (Massonnat, 1999). This study focuses on reservoir models that depend on geostatistical methods. This is accomplished by quantifying the uncertainty in outcome of reservoir simulations as six different geological variables are changed during a succession of reservoir simulations. In this study, variations in total fluid produced are examined by numerical modeling. Causes of uncertainty in outcomes of the model runs are examined by changing one of six geological parameters for each run. The six geological parameters tested for their impact on reservoir performances include the following: 1) variogram range used to krig thickness layers, 2) morphology around well 14, 3) shelf edge orientation, 4) bathymetry ranges attributed for each facies, 5) variogram range used to simulate facies distribution, 6) extension of the erosion at top of the reservoir. The parameters were assigned values that varied from a minimum to a maximum quantity, determined from petrophysical and core analysis. After simulation runs had been completed, a realistic, 3-dimensional reservoir model was developed that revealed a range of reservoir production data. The parameters that had the most impact on reservoir performance were: 1) the amount of rock eroded at the top of the reservoir zone and 2) the bathymetry assigned to the reservoir facies. This study demonstrates how interaction between geological parameters influence reservoir fluid production, how variations in those parameters influence uncertainties in reservoir simulations, and it highlights the interdependencies between geological variables. The analysis of variance method used to quantify uncertainty in this study was found to be rapid, accurate, and highly satisfactory for this type of study. It is recommended for future applications in the petroleum industry.
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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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Books on the topic "Reservoir geology"

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Zoback, Mark D. Reservoir geomechanics. Cambridge: Cambridge University Press, 2010.

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Petroleum reservoir engineering practice. Upper Saddle River, NJ: Prentice Hall, 2011.

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Bagrint︠s︡eva, K. I. Carbonate reservoir rocks. Hoboken, New Jersey: John Wiley & Sons, 2015.

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Narr, Wayne. Naturally fractured reservoir characterization. Richardson, TX: Society of Petroleum Engineers, 2006.

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Ezekwe, Nnaemeka. Petroleum reservoir engineering practice. Upper Saddle River, NJ: Prentice Hall, 2011.

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A, Beier Richard, ed. Fractals in reservoir engineering. Singapore: World Scientific, 1994.

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Fanchi, John R. Principles of applied reservoir simulation. Houston, Tex: Gulf Pub., 1997.

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Principles of applied reservoir simulation. 2nd ed. Boston: Gulf Pub., 2001.

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Reservoir formation damage: Fundamentals, modeling, assessment, and mitigation. 2nd ed. Amsterdam: Gulf Professional Pub., 2007.

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Reservoir formation damage: Fundamentals, modeling, assessment, and mitigation. Houston, TX: Gulf Pub. Co., 2000.

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Book chapters on the topic "Reservoir geology"

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Wang, Jiahong. "Reservoir Geology." In Waterflooding Sandstone Reservoirs: Methods, Design and Analysis, 21–63. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-0348-8_2.

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Ma, Xinhua. "Shaan224 Reservoir Geology and Development." In Handbook of Underground Gas Storages and Technology in China, 1–24. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-7855-7_7-1.

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Jia, Chengzao. "Petroleum Geology of Carbonate Reservoir." In Characteristics of Chinese Petroleum Geology, 495–532. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-23872-7_12.

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Liu, Dehua, and Jing Sun. "Well Pattern Models for Different Reservoir Characteristics." In Springer Geology, 179–223. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-53287-4_5.

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Liu, Dehua, and Jing Sun. "Reservoir Direction Characteristics Investigation and Permeability Distribution Law." In Springer Geology, 61–98. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-53287-4_2.

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Hewett, Thomas A. "Modelling Reservoir Heterogeneity with Fractals." In Quantitative Geology and Geostatistics, 455–66. Dordrecht: Springer Netherlands, 1993. http://dx.doi.org/10.1007/978-94-011-1739-5_36.

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Ma, Xinhua. "Banqiao Reservoir Geology and Storage Design." In Handbook of Underground Gas Storages and Technology in China, 1–19. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-7855-7_2-1.

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Dubrule, Olivier. "Introducing More Geology in Stochastic Reservoir Modelling." In Quantitative Geology and Geostatistics, 351–69. Dordrecht: Springer Netherlands, 1993. http://dx.doi.org/10.1007/978-94-011-1739-5_29.

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Deutsch, Clayton V. "Conditioning Reservoir Models to Well Test Information." In Quantitative Geology and Geostatistics, 505–18. Dordrecht: Springer Netherlands, 1993. http://dx.doi.org/10.1007/978-94-011-1739-5_40.

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Jia, Chengzao. "Exploration Examples for Lithostratigraphic Petroleum Reservoir." In Characteristics of Chinese Petroleum Geology, 271–329. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-23872-7_8.

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Conference papers on the topic "Reservoir geology"

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Lagkaditi, Lydia, Ashok Srivastava, and Anuj Gupta. "Geology-Based Reservoir Model Building for Carbonate Reservoirs." In ASME 2013 32nd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/omae2013-11328.

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Environment in which carbonate reservoir rocks are deposited was studied by visiting and collecting rock samples from a carbonate reservoir analog located at Jabal Fuwairit in the Northeastern coast of Qatar. The primary objective of this study is to develop methods to characterize carbonate reservoirs. The experimental procedure included collecting samples based on geology, mapping the location and altitudes of the samples using a high-resolution Global Positioning System (GPS) with an altimeter, permeability measurements at selected locations, conducting petrophysical measurements on the samples, Conventional and Micro-X-ray Computed Tomography Scanning (CT Scanning), Scanning Electron Microscopy (SEM), X-ray Energy Dispersive Spectroscopy (EDS) and Atomic Force Microscopy (AFM) imaging. It is observed that the permeability measurements show an alternating pattern as a function of height above sea level. The cyclicity is probably representative of repeating sequences of sea level changes over geological time. CT Scanner and Micro-CT Scanner measurements were employed to obtain vital information about the flow pathways in the rock, thus assisting in calculating the porosity to compare with values measured in the lab. SEM results gave direct visualization of the pore network and information about grain size (500 microns) and intergranular porosity, mineralogy, compared with the EDS results, and lithotype. EDS results showed that reservoir rocks directly exposed to environment had significant alteration due to weathering. However, it is encouraging to learn that samples even few inches away from the surface had minimal environmental influence.
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Al Farqani, S. Z., I. G. Perez, and M. Claps and H. Peters. "Diagenesis Control on Reservoir Properties of a Permian Triassic Carbonate Reservoir, North Oman." In Third Arabian Plate Geology Workshop. Netherlands: EAGE Publications BV, 2011. http://dx.doi.org/10.3997/2214-4609.20144067.

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Burmester, G., and K. A. T. MacPherson. "The Key to High Resolution Reservoir Characterization." In EAGE Borehole Geology Workshop. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20142319.

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Rahaman, M., and M. Ebrahim and S. Al-Ghareeb. "Prospectivity of Khuff Reservoir in Southwest Kuwait." In Third Arabian Plate Geology Workshop. Netherlands: EAGE Publications BV, 2011. http://dx.doi.org/10.3997/2214-4609.20144084.

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Knaust, Dirk. "Importance of Trace Fossils and Bioturbation in Carbonate Reservoir Characterization and Reservoir Quality: Examples from the Khuff Formation." In Third Arabian Plate Geology Workshop. Netherlands: EAGE Publications BV, 2011. http://dx.doi.org/10.3997/2214-4609.20144063.

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Cosson, C., S. Ducroux, and L. Van den Brul. "Geology To Geomechanics Integrated Workflow For Better Production Risk Management." In EAGE Conference on Reservoir Geoscience. European Association of Geoscientists & Engineers, 2018. http://dx.doi.org/10.3997/2214-4609.201803255.

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Al-Rashdi, M., M. Al-Raisi, F. Knap, S. Bulushi, and F. Al Jahwari. "Borehole Imaging Challenges and Added Value in Fracture Reservoir Characterisation." In EAGE Borehole Geology Workshop. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20142322.

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Mildren, S., R. Nicolson, S. Holford, and L. Titus. "Improved Reservoir Models Utilising Image Log Data for a Multidisciplinary Workflow." In EAGE Borehole Geology Workshop. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20142337.

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Dubrule, O., C. Basire, S. Bombarde, Ph Samson, D. Segonds, and J. Wonham. "Reservoir Geology Using 3-D Modelling Tools." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/38659-ms.

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Hon, Vai Yee, M. Faizzudin Mat Piah, Noor 'Aliaa M Fauzi, Peter Schutjens, Binayak Agarwal, and Rob Harris. "Integrated Reservoir Geomechanics Approach for Reservoir Management." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21216-ms.

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Abstract An integrated 3D dynamic reservoir geomechanics model can provide a diverse 3D view of depletion-injection-induced field stress changes and the resulting deformation of both reservoir and overburden formations at various field locations. It enables the assessment of reservoir compaction, platform site subsidence, fault reactivation and caprock integrity associated with multiple production and injection reservoirs of the field. We demonstrated this integrated approach for a study field located in the South China Sea, Malaysia, which is planned for water injection for pressure support and EOR scheme thereafter. Reservoir fluid containment during water injection is an important concern because of the intensive geologic faulting and fracturing in the collapsed anticlinal structure, with some faults extending from the reservoirs to shallow depths at or close to the seafloor. Over 30 simulations were done, and most input parameters were systematically varied to gain insight in their effect on result that was of most interest to us: The tendency of fault slip as a function of our operation-induced variations in pore pressure in the reservoir rocks bounding the fault, both during depletion and injection. The results showed that depletion actually reduces the risk of fault slip and of the overburden, while injection-induced increase in pore fluid pressure will lead to a significant increase in the risk of fault slip. Overall, while depletion appears to stabilize the fault and injection appears to destabilize the fault, no fault slip is predicted to occur, not even after a 900psi increase in pore pressure above the pore pressure levels at maximum depletion. We present the model results to demonstrate why depletion and injection have such different effects on fault slip tendency. The interpretation of these geomechanical model results have potential applications beyond the study field, especially for fields with a similar geology and development plan. This is a novel application of 3D dynamic reservoir geomechanics model that cannot be obtained from 1D analytical models alone.
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Reports on the topic "Reservoir geology"

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McMechan, M. E. Geology, Spray Lakes Reservoir, Alberta - British Columbia. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2012. http://dx.doi.org/10.4095/288954.

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Paulen, R. C., J. M. Rice, and M. B. McClenaghan. Surficial geology, northwest Smallwood Reservoir, Newfoundland and Labrador, NTS 23-I southeast. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2017. http://dx.doi.org/10.4095/300685.

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Glenn, R., and W. Allen. Geology, reservoir engineering and methane hydrate potential of the Walakpa Gas Field, North Slope, Alaska. Office of Scientific and Technical Information (OSTI), December 1992. http://dx.doi.org/10.2172/6638599.

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Glenn, R. K., and W. W. Allen. Geology, reservoir engineering and methane hydrate potential of the Walakpa Gas Field, North Slope, Alaska. Final report. Office of Scientific and Technical Information (OSTI), December 1992. http://dx.doi.org/10.2172/10142661.

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Ann Mattson, Craig B. Forster, Paul B. Anderson, Steve H. Snelgrove, and Jr Thomas C. Chidsey. Geology and Petrophysical Characterization of the Ferron Sandstone for 3-D Simulation of a Fluvial-Deltaic Reservoir. Office of Scientific and Technical Information (OSTI), May 1997. http://dx.doi.org/10.2172/1627.

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Chidsey, T. C. Jr, P. B. Anderson, T. H. Morris, J. A. Jr Dewey, A. Mattson, C. B. Foster, S. H. Snelgrove, and T. A. Ryer. Geology and petrophysical characterization of the Ferron Sandstone for 3-D simulation of a fluvial-deltaic reservoir. Annual report, October 1, 1996--September 30, 1997. Office of Scientific and Technical Information (OSTI), May 1998. http://dx.doi.org/10.2172/610909.

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Helmold, K. P. Petrology & reservoir quality of Cook Inlet sandstones - regional perspective (presentation): U.S. Geological Survey Cook Inlet Geology Review Meeting, Anchorage Alaska, September 21-22, 2010. Alaska Division of Geological & Geophysical Surveys, September 2010. http://dx.doi.org/10.14509/21804.

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Law, B. E. Geologic characterization of tight gas reservoirs. Office of Scientific and Technical Information (OSTI), December 1990. http://dx.doi.org/10.2172/5614026.

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Berndt, Christian. RV SONNE Fahrtbericht / Cruise Report SO277 OMAX: Offshore Malta Aquifer Exploration, Emden (Germany) – Emden (Germany), 14.08. – 03.10.2020. GEOMAR Helmholtz Centre for Ocean Research Kiel, January 2021. http://dx.doi.org/10.3289/geomar_rep_ns_57_20.

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SO277 OMAX served two scientific projects. The objectives of the first project, SMART, were to develop multi-disciplinary methodologies to detect, quantify, and model offshore groundwater reservoirs in regions dominated by carbonate geology such as the Mediterranean Sea. To this end we acquired controlled-source electromagnetic, seismic, hydroacoustic, geochemical, seafloor imagery data off Malta. Preliminary evaluation of the geophysical data show that there are resisitivity anomalies that may represent offshore freshwater aquifers. The absence of evidence for offshore springs means that these aquifers would be confined and that it will be difficult to use them in a sustainable manner. The objective of the second project, MAPACT-ETNA, is to monitor the flank of Etna volcano on Sicily which is slowly deforming seaward. Here, we deployed six seafloor geodesy stations and six ocean bottom seismometers for long-term observation (1-3 years). In addition, we mapped the seafloor off Mt. Etna and off the island of Stromboli to constrain the geological processes that control volcanic flank stability.
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John Rogers. Integrated Reflection Seismic Monitoring and Reservoir Modeling for Geologic CO2 Sequestration. Office of Scientific and Technical Information (OSTI), December 2011. http://dx.doi.org/10.2172/1039999.

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