Relevant bibliographies by topics / Reservoir properties

Contents

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

Academic literature on the topic 'Reservoir properties'

Author: Grafiati
Published: 4 June 2021
Last updated: 16 November 2024

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Journal articles on the topic "Reservoir properties"

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Zhou, Tianqi, Hongqi Yuan, Fengming Xu, and Rigen Wu. "Tight Sandstone Reservoir Characteristics and Controlling Factors: Outcrops of the Shanxi Formation, Liujiang River Basin, North China." Energies 16, no. 10 (May 16, 2023): 4127. http://dx.doi.org/10.3390/en16104127.

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Tight sandstone reservoirs are of interest due to their potentially favorable prospects for hydrocarbon exploration. A better understanding of tight sandstone outcrop reservoir characteristics and their influencing factors is thus needed. By laboratory observation, thin section analysis, and experimental analysis, the current work carried out a detailed investigation of densely sampled tight sandstone outcrops of the Shanxi Formation in the Liujiang River Basin, paving the way for further research on rock types, reservoir spatial distribution, physical properties, and their key controlling factors. The application of the Pressure Pulse Attenuation Method made it possible to determine the porosity and permeability, as well as the analysis of debris composition and filling content. The findings indicate that the main rock type of the tight sandstone outcrop reservoirs in the Shanxi Formation in the Liujiang River Basin is lithic quartz sandstone, some of which contains fine sand-bearing argillaceous siltstone, giving them very low porosity (average porosity of 4.34%) and low permeability (average permeability of 0.023 mD) reservoirs. Secondary pores—mostly dissolved pores among and in grains—are widely developed in the target region. In addition, diagenesis primarily includes mechanical compaction, cementation, and dissolution. The main controlling factors of tight sandstone reservoirs in the target region are sedimentation, diagenesis, and tectonics, whereby sedimentation affects reservoir physical properties that become better as the clast size increases, reservoir properties are negatively impacted by compaction and cementation, and reservoir properties are somewhat improved due to dissolution and the impact of tectonism. In addition, the tilt of the crust will produce faults during the tectonic action, generating reservoir cracks that improve the reservoir’s physical properties. This study tends to be helpful in the prediction of high-quality reservoirs in the Permian Shanxi Formation in North China and can also be used for analogy of high-quality reservoirs in similar areas with complete outcrops.
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Miotti, Fabio, Andrea Zerilli, Paulo T. L. Menezes, João L. S. Crepaldi, and Adriano R. Viana. "A new petrophysical joint inversion workflow: Advancing on reservoir’s characterization challenges." Interpretation 6, no. 3 (August 1, 2018): SG33—SG39. http://dx.doi.org/10.1190/int-2017-0225.1.

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Reservoir characterization objectives are to understand the reservoir rocks and fluids through accurate measurements to help asset teams develop optimal production decisions. Within this framework, we develop a new workflow to perform petrophysical joint inversion (PJI) of seismic and controlled-source electromagnetic (CSEM) data to resolve for reservoirs properties. Our workflow uses the complementary information contained in seismic, CSEM, and well-log data to improve the reservoir’s description drastically. The advent of CSEM, measuring resistivity, brought the possibility of integrating multiphysics data within the characterization workflow, and it has the potential to significantly enhance the accuracy at which reservoir properties and saturation, in particular, can be determined. We determine the power of PJI in the retrieval of reservoir parameters through a case study, based on a deepwater oil field offshore Brazil in the Sergipe-Alagoas Basin, to augment the certainty with which reservoir lithology and fluid properties are constrained.
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Yin, Rongwang, Qingyu Li, Peichao Li, and Detang Lu. "A Novel Method for Matching Reservoir Parameters Based on Particle Swarm Optimization and Support Vector Machine." Mathematical Problems in Engineering 2020 (April 29, 2020): 1–10. http://dx.doi.org/10.1155/2020/7542792.

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When the reservoir physical properties are distributed very dispersedly, the matching precision of these reservoir parameters is not good. We propose a novel method for matching the reservoir physical properties based on particle swarm optimization (PSO) and support vector machine (SVM) algorithm. First, the data structure characteristics of the reservoir physical properties are analyzed. Then, the particle swarm differential perturbation evolution algorithm is used to cluster and characterize the reservoir physical properties. Finally, by using the SVM algorithm for feature reorganization and the least squares matching of the extracted reservoir physical properties, the feature quantity of the reservoir physical properties can be accurately mined and the pressure matching precision is improved. The experimental results show that employing the proposed method to analyze and sample the data characteristics of the physical properties of the reservoir is better. The extracted parameters can effectively reflect the physical characteristics of oil reservoirs. The proposed method has potential applications in guiding the exploration and development of oil reservoirs.
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Shin, Seungwon, Sangbeen Lee, Sungsu Lee, and Jongwon Jung. "Evaluation of Slope Stability of Reservoir Considering Heterogeneous Soil Properties." Journal of the Korean Society of Hazard Mitigation 20, no. 6 (December 31, 2020): 167–75. http://dx.doi.org/10.9798/kosham.2020.20.6.167.

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The slope stability evaluation of reservoirs is required because of the aging of reservoirs. Reservoir levees are designed to achieve homogeneous construction, but the spatial heterogeneity of the material properties of reservoirs is unavoidable. Because the existing method for evaluating reservoir stability is limited in terms of considering the spatial heterogeneity of material properties, the stability evaluation was conducted in this study, in which the spatial heterogeneity and uncertainty of the material properties of the reservoir levee were considered. In addition, the results for the existing and proposed methods were compared and analyzed, and the variability of the entire material properties of the reservoir levee, instead of spatial heterogeneity, was reflected. The evaluation results confirmed that the probability of failure obtained using the proposed method was lower than that for the existing stability evaluation method, considering the variations in material properties because the levee did not reach the critical state, owing to changes in local properties. Therefore, the proposed method is useful for the cost-effect repair and reinforcement of reservoir slopes, compared to the existing slope stability evaluation method.
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Yang, Tao, Ibnu Hafidz Arief, Martin Niemann, and Marianne Houbiers. "Reservoir Fluid Data Acquisition Using Advanced Mud-Logging Gas in Shale Reservoirs." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 65, no. 4 (August 1, 2024): 455–69. http://dx.doi.org/10.30632/pjv65n4-2024a2.

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Oil production from shale reservoirs has increased dramatically in recent years. To identify drilling targets and optimize well completions, it is important to get early access to reservoir fluid properties. However, due to the low permeability of shale reservoirs, fluid samples often become available only after the most important development decisions have been made. Therefore, it has been an abiding challenge in the industry how to acquire fluid properties data earlier in shale reservoirs. Mud-logging gas data acquired while drilling provide the earliest hydrocarbon response from the reservoir. In an earlier study, we demonstrated that advanced mud gas data have a large potential to predict reservoir fluid properties. In general, fluid properties are strongly correlated with the thermal maturity of the source rock. In shale reservoirs, reservoir fluids are still in the source rock, as low permeability limits the migration and convection of the reservoir fluids. As a result, the reservoir fluid systems in shale reservoirs are relatively undisturbed and have a high degree of consistency. This provides the possibility to correlate advanced mud-logging gas data and reservoir fluid properties. Based on a reservoir fluid database with more than 60 samples from different shale reservoirs, we developed a machine-learning algorithm to predict fluid properties from advanced mud-logging gas data. The accuracy of the new method is significantly improved compared with the previous model, which used an explicit correlation based on wetness. In addition, the new approach is more general and does not depend on a specific shale reservoir. We applied the new model to 11 wells with advanced mud-logging gas data. The predicted gas-oil ratios (GOR) are close to the measurement from early production data when advanced mud-logging gas data are of good quality. This publication demonstrates that advanced mud-logging gas data can be used to predict reservoir fluid properties in shale reservoirs. Such an approach provides a novel and cost-efficient solution for the sampling challenges in the early phase. In addition, the method provides continuous fluid data along the entire well, as opposed to a single fluid sample taken at a specific location. Hence, the results provide insight into the fluid distribution in shale reservoirs. The method can be widely used for sweet spot identification and optimizing fracking strategy in shale reservoirs.
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Valluri, Manoj Kumar, Jimin Zhou, Srikanta Mishra, and Kishore Mohanty. "CO2 Injection and Enhanced Oil Recovery in Ohio Oil Reservoirs—An Experimental Approach to Process Understanding." Energies 13, no. 23 (November 26, 2020): 6215. http://dx.doi.org/10.3390/en13236215.

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Process understanding of CO2 injection into a reservoir is a crucial step for planning a CO2 injection operation. CO2 injection was investigated for Ohio oil reservoirs which have access to abundant CO2 from local coal-fired power plants and industrial facilities. In a first of its kind study in Ohio, lab-scale core characterization and flooding experiments were conducted on two of Ohio’s most prolific oil and gas reservoirs—the Copper Ridge dolomite and Clinton sandstone. Reservoir properties such as porosity, permeability, capillary pressure, and oil–water relative permeability were measured prior to injecting CO2 under and above the minimum miscibility pressure (MMP) of the reservoir. These evaluations generated reservoir rock-fluid data that are essential for building reservoir models in addition to providing insights on injection below and above the MMP. Results suggested that the two Ohio reservoirs responded positively to CO2 injection and recovered additional oil. Copper Ridge reservoir’s incremental recovery ranged between 20% and 50% oil originally in place while that of Clinton sandstone ranged between 33% and 36% oil originally in place. It was also deduced that water-alternating-gas injection schemes can be detrimental to production from tight reservoirs such as the Clinton sandstone.
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Abdulrazzaq, Tuqa, Hussein Togun, Dalia Haider, Mariam Ali, and Saja Hamadi. "Determining of reservoir fluids properties using PVTP simulation software- a case study of buzurgan oilfield." E3S Web of Conferences 321 (2021): 01018. http://dx.doi.org/10.1051/e3sconf/202132101018.

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The measurement of oil reservoirs and their performance with hydrocarbon reservoirs is used to distinguish the properties of reservoir fluids, which is significant in various reservoir studies. As a result, in the various oil industries, adopting the appropriate methods to obtain accurate property values is very important. The current paper is about a case study of the BUZURGAN Oilfield and how the PVTp software was used to predict phase activity and physical properties. To understand the properties of fluids for the reservoir and phase behavior, the black oil model and the equation of state (EoS) model are used. (Glaso) correlation is used to calculate the bubble point strain, solubility, and formation volume factor. The Beal's correlation was also used to measure viscosity, while the equation of state (EoS) model was used to determine phase behavior and density. Furthermore, the properties of PVT were discovered using the software, and the results were compared to laboratory analysis of PVT, with suitable models being displayed. According to the findings, the used model has the highest saturation pressure, which was chosen for use in reservoir management processes and the preparation of a geological model to reflect the field later. It is clear that the program is appropriate due to the accurate dependence of PVT measurements on laboratory tests in the case that tests are required during the reservoir's productive existence.
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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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Novruzova, S. H., and I. N. Aliyev. "Determination of Reservoir Characteristics Oil Well Producing Non-Newtonian Oil, Taking into Account the Temperature Situation in the Reservoir." Oil and Gas Technologies 150, no. 1 (2024): 40–42. http://dx.doi.org/10.32935/1815-2600-2024-150-1-40-42.

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The article investigates the problem of determining the reservoir properties of non-Newtonian oil reservoirs developed in the depletion mode, the rocks of which are subjected to elastic deformation. Various methods (identification and graphic-analytical) for determining the reservoir properties of non-Newtonian oil reservoirs are proposed, takinginto account the temperature situation. The determined reservoir properties of the formations are: porosity and permeability of the formations, the initial pressure gradient, as well as the current well drainage radius.
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Mondal, Samit, Rima Chatterjee, and Shantanu Chakraborty. "An integrated approach for reservoir characterisation in deep-water Krishna-Godavari basin, India: a case study." Journal of Geophysics and Engineering 18, no. 1 (February 2021): 134–44. http://dx.doi.org/10.1093/jge/gxab002.

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Abstract The Miocene reservoirs in prolific Krishna-Godavari basin are mostly fluvial deposits and laminated or blocky in nature. The type of reservoir quality depends on associated geological environments. Due to several lateral variations in reservoir properties, a similar kind of workflow for reservoir characterisation does not work. Customised workflow needs to be applied in this area for estimation of petrophysical properties or rock physical analysis for reservoir quality prediction. As the major input of rock physical analysis is petrophysical properties, it is crucial to estimate these properties accurately. Meanwhile, it is also important to check the seismic sensitivity to change in fluid saturation in the reservoir characterisation process. The analysis assures the presence of reservoir and hydrocarbon contact in seismic sensitivity, which is essential for removing risk. Integrating the geological model with rock physical analysis for reservoir characterisation at the drilled well, the reservoir quality at undrilled prospects is predicted. In this study, the comprehensive study for reservoir characterisation of Miocene reservoirs consists of three different steps: calculation of petrophysical properties for mixed of thick and laminated sequence, rock physical analysis for identification of hydrocarbon reservoir and corresponding seismic sensitivity for change in saturation and finally the rock physics template for prediction of reservoir quality away from the drilled well. Results from the study have added significant value in de-risking the number of undrilled prospects in this area.
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Dissertations / Theses on the topic "Reservoir properties"

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AlBinHassan, Nasher M. "Reservoir properties prediction in carbonate reservoirs." Thesis, Imperial College London, 2010. http://hdl.handle.net/10044/1/5922.

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Prediction of fluid pressure before drilling, using geophysical methods helps the industry a lot in saving human life, drilling hazards, and equipments.There are several geophysical methods available to predict the fluid pressure before drilling but the most commonly used in the industry are those based on seismic velocities. However, seismic velocities methods are applied on clastic reservoirs with the assumptions that the pressure mechanism is due to mechanical compaction. A major exploration challenge is to successfully predict the presence of high pressure zones in the carbonate reservoirs. Carbonate reservoirs have a more complicated internal structure than clastic reservoirs. The main objective of this study is to predict the carbonate reservoir properties such as porosity and fluid pressure. The new prediction methods that I used in this thesis are called the artificail intelligent algorithms. These algorithms are better than the conventional geophysical methods because of their ability to explore complex relationships between the input seismic attributes and the predicted properties. The algorithms include artificial neural networks and group methods of data handling. Empirical equations from seismic prediction methods were used to transform velocities to fluid pressure. High resolution velocites (wavefrom tomography) proved that better prediction can be achieved when using better input velocity. The velocity methods performed a nice prediction when used with clastic seismic data but proved to give unreliable results when used with the carbonate seismic data. This was because of the difficult internal structure of carbonate reservoirs. The neural network methods proved that they are robust in clustering and segmenting the input carbonate seismic data. The usage of more input seismic attributes made the neural network methods better than the conventional velocity methods. Also, this gave the neural network methods more information about the same physical reservoir property. Among the different seismic attributes used in the experiment, seismic inversion and coherence attributes showed good reaction to high pressure zones. Porosity results from the supervised neural network method were used as a guide to the unsupervised neural network method to predict fluid pressure. The group method of data handling algorithm is performed here for the first time with seismic data to predict the reservoir properties. The new method showed faster and easier prediction than the neural network methods. The automation of the new method yields to better porosity and pore pressure prediction.
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Lee, Tai-yong Seinfeld John H. "Estimation of petroleum reservoir properties /." Diss., Pasadena, Calif. : California Institute of Technology, 1987. http://resolver.caltech.edu/CaltechETD:etd-03012008-135126.

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Yang, Huade. "Relationships between petrophysical properties and petrographic properties of reservoir rocks /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.

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Aasum, Yngve. "Effective properties of reservoir simulator grid blocks /." Access abstract and link to full text, 1992. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9300177.

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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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Li, Xuesong. "Interfacial properties of reservoir fluids and rocks." Thesis, Imperial College London, 2013. http://hdl.handle.net/10044/1/14380.

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Interfacial phenomena between CO2, brines or hydrocarbon, and carbonate rocks were investigated with the aim of understanding key aspects on CO2 storage and enhanced oil recovery (EOR) in carbonate reservoirs. The interfacial tensions between brines and CO2 were studied systematically with variation of the salt type and concentration under conditions applicable to the field. The results of the study indicate that, for strong electrolytes, the interfacial tension increases linearly with the positive charge concentration. Empirical models have been developed that represent the results as a function of temperature, pressure and molality with the small absolute average relative deviation of about 2 %. The interfacial tension measured between brine and crude oils indicated that interfacial tension has a strong dependence on both the viscosity of crude oil and the salinity of the brine. Molecular dynamics (MD) simulations of interfacial tension between water or brine and CO2 were carried out to investigate microscopic interfacial phenomena and to further understand the dependence of interfacial tension on temperature, pressure, and brine salinity. The simulation results were consistent with the experimental data obtained in this study. In particular, the simulations showed that the interfacial tension is linearly dependent on the positive charge concentration for strong electrolytes, most likely due to desorption of ions on the interface between brine and CO2. The contact angle of brine and crude oil on carbonate rocks was measured at both ambient and reservoir conditions. The results indicate that brine salinity has a strong effect on the wettability of the carbonate rock surface. This thesis provided the first attempt to explain the low salinity effect from the interactions between brine and rocks. Contact angle results and wettability index gathered from the NMR and Amott approaches measured on porous rocks were compared and found to be correlated in (crude oil + brine + calcite) systems at ambient condition. Molecular dynamics simulations of contact angle were carried out to give a deeper understanding of the underlying mechanism of the effect of brine salinity on wettabilty. Together with the experimental evidence, it can be concluded that increasing the salinity of brine results in an increase of the interfacial tension between calcite and brine. This is the first attempt to simulate contact angles by IFT simulations. Over all, interfacial phenomena between reservoir rocks and fluids were investigated by interfacial tension and contact angle measurement and by molecular simulation. Based on the wide range of experimental and simulation data obtained, this thesis provides a near complete understanding of the brine and CO2 interfacial behaviour under reservoir conditions. The empirical models obtained can predict reliably essentially any interfacial tension between brine and CO2 at reservoir conditions with given brine composition, temperature and pressure. MD simulations together with the experimental evidence, indicate that reducing the salinity of brine generally reduces the adhesion tension of crude oil in brine and calcite system. Thus proving that low salinity water flooding could potentially increase oil recovery from carbonate reservoir. More generally, low salinity aquifers are found to be more favourable for CO2 trapping.
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Kim, Samantha. "Deriving Geothermal Reservoir Properties from Tomographic Models." Thesis, Uppsala universitet, Institutionen för geovetenskaper, 2019. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-399927.

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The effectiveness of the heat transfer in a geothermal reservoir strongly depends on its temperature, pressure and rock type. A porous and fractured rock is essential to provide a hot fluid circulation to a geothermal power plant. Velocity anomalies in seismic tomography may relate to the location of a fluid reservoir, hydrothermal systems, and possible heat sources. However, the subsurface properties like porosity, fracture density, and fluid state (e.g liquid, gas or supercritical fluid) cannot be inferred directly using seismic tomography. The inversion of seismic data can be combined with an effective medium model (EMM) to investigate such rock and subsurface properties. In the present study, we implement an EMM involving elastic rock properties and the following descriptions of inclusions: pore porosity, fracture density, fracture aspect ratio, fracture porosity, and liquid ratio. The chosen EMM was reproduced from the work of Adelinet et al. (2011a) and Adelinet (2010). Tomographic results were inverted for the same geographic area (Krysuvik in Iceland) in order to validate our method and to confirm the presence of the supercritical fluid reservoir. We re-evaluate the assumptions and constraining parameters choice of the inverse model used in Adelinet et al. (2011a) and Adelinet (2010), in order to 1) get a better understanding of the underlying problems, 2) investigate the sensitivity of the results based on the constraining parameters, 3) produce suitable workflows, and 4) build an adaptive method for geothermal exploration in different areas. The newly implemented method found the same qualitative results in Krysuvik as Adelinet et al. (2011a). Namely, at ≈ 6.5 km depth both values of fracture density and of liquid ratio are consistent with hydraulic fracturing and a probable super-critical fluid reservoir. Afterwards, the method was applied to the Hengill volcanic complex. Fracture density and liquid ratio values similar to those observed at Krysuvik and associated to a geothermal reservoir were obtained at Hengill at the exact location of existing production sites. Our results also showed limitations of initial assumptions and could contribute to improve the method. This study could be a starting point to build a more sophisticated tool for geothermal exploration.
Idag består majoriteten av världens energiproduktion av fossilt bränsle. Naturgas, kol och olja stod tillsammans för 70% av världens energiproduktion 2010 och det ökar konstant trots nödvändigheten att minska koldioxidutsläppen. Geotermisk energi är en hållbar resurs men bidrar endast med mindre än 2% av världens energi. Det finns dock undantag, exempelvis på Island där 70% av all energi som förbrukas kommer från geotermiska resurser. Island är en seismiskt aktiv region som inkluderar diverse olika geotermiska områden med hög temperatur. På grund av detta, har det där skett mycket forskning om geotermiska resurser. Vidare information är nödvändig för att utforska potentialen av att nyttja geotermisk energi. I denna studie impementerades en metod som kombinerar seismiska hastigheter och teoretiska mekaniska egenskaper av stenar, exempelvis stenbrottsgeometri. Metoden tillåter att uttyda egenskaper under ytan, framförallt tätheten av sprickor och det fysiska tillståndet av vätskan. Dessa egenskaper kan bidra med relevant information för beslutstagande och är nödvändiga för att lyckas med borrning. En optimering av mätna och teoeriska värden var beräknad för att hitta de optimala värdena av spricktäthet och det fysiska tillståndet av vätskan. Studien fokuserar huvudsakligen på två geotermiska områden på Island, Krysuvik- och Hengill-vulkanernas områden. Resultat erhållna från Krysuvik konfimerade en möjlig superkritisk vätskereservoar på ettdjup av 5.5-6.5 kilometer. Efter att ha studerat Hengill-området, uppkom resultat på den geotermiska utvinningsplatsen men det visade även begränsningar kring metoden. Metoden behöver förbättras och anpassa sig till funktionen av området. Heterogeniteten och de komplexa egenskaperna (till exempel bergskomposition eller vätskealternering) under ytan ledde till omvärdering av antaganden gjorda i den initiala mediummodellen.
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Pérez, Godofredo. "Stochastic conditional simulation for description of reservoir properties /." Access abstract and link to full text, 1991. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9203796.

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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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Berhanu, Solomon Assefa. "Seismic and petrophysical properties of carbonate reservoir rocks." Thesis, University of Reading, 1994. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.262633.

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Books on the topic "Reservoir properties"

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Ganat, Tarek Al-Arbi Omar. Fundamentals of Reservoir Rock Properties. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-28140-3.

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Badawy, Amr Mohamed, and Tarek Al Arbi Omar Ganat. Rock Properties and Reservoir Engineering: A Practical View. Cham: Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-030-87462-9.

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Ahmed, Tarek H. Working guide to reservoir rock properties and fluid flow. Amsterdam: Elsevier, 2010.

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Lee, Roger W. Light attenuation in a shallow, turbid reservoir, Lake Houston, Texas. Austin, Tex: U.S. Dept. of the Interior, U.S. Geological Survey, 1997.

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Tiab, Djebbar. Petrophysics: Theory and practice of measuring reservoir rock and fluid transport properties. Houston, Tex: Gulf Pub. Co., 1996.

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C, Donaldson Erle, ed. Petrophysics: Theory and practice of measuring reservoir rock and fluid transport properties. 2nd ed. Boston: Gulf Professional Pub., 2004.

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C, Donaldson Erle, ed. Petrophysics: Theory and practice of measuring reservoir rock and fluid transport properties. 3rd ed. Amsterdam: Gulf Professional Pub., 2012.

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Gessner, Tobias R., and Jader R. Barbosa. Integrated Modeling of Reservoir Fluid Properties and Multiphase Flow in Offshore Production Systems. Cham: Springer International Publishing, 2023. http://dx.doi.org/10.1007/978-3-031-39850-6.

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Tiab, Djebbar. Petrophysics: Theory and practice of measuring reservoir rock and fluid transport properties ; solutions manual. Houston, Tex: Gulf Pub. Co., 1997.

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Mazo, Aleksandr, and Konstantin Potashev. The superelements. Modeling of oil fields development. ru: INFRA-M Academic Publishing LLC., 2020. http://dx.doi.org/10.12737/1043236.

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This monograph presents the basics of super-element modeling method of two-phase fluid flows occurring during the development of oil reservoir. The simulation is performed in two stages to reduce the spatial and temporal scales of the studied processes. In the first stage of modeling of development of oil deposits built long-term (for decades) the model of the global dynamics of the flooding on the super-element computational grid with a step equal to the average distance between wells (200-500 m). Local filtration flow, caused by the action of geological and technical methods of stimulation, are modeled in the second stage using a special mathematical models using computational grids with high resolution detail for the space of from 0.1 to 10 m and time — from 102 to 105 C. The results of application of the presented models to the solution of practical tasks of development of oil reservoir. Special attention is paid to the issue of value transfer in filtration-capacitive properties of the reservoir, with a detailed grid of the geological model on the larger grid reservoir models. Designed for professionals in the field of mathematical and numerical modeling of fluid flows occurring during the development of oil fields and using traditional commercial software packages, as well as developing their own software. May be of interest to undergraduate and graduate students studying in areas such as "Mechanics and mathematical modeling", "Applied mathematics", "Oil and gas".
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Book chapters on the topic "Reservoir properties"

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Bateman, Richard M. "Reservoir Fluid Properties." In Cased-Hole Log Analysis and Reservoir Performance Monitoring, 31–64. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-017-0977-4_3.

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Bateman, Richard M. "Reservoir Fluid Properties." In Cased-Hole Log Analysis and Reservoir Performance Monitoring, 17–50. New York, NY: Springer New York, 2014. http://dx.doi.org/10.1007/978-1-4939-2068-6_3.

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Tewari, Raj Deo, Abhijit Y. Dandekar, and Jaime Moreno Ortiz. "Reservoir Fluid Properties." In Petroleum Fluid Phase Behavior, 1–57. First edition. | Boca Raton, FL : CRC Press/Taylor & Francis Group, 2019. | Series: Emerging trends & technologies in petroleum engineering: CRC Press, 2018. http://dx.doi.org/10.1201/9781315228808-1.

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Ringrose, Philip, and Mark Bentley. "Upscaling Flow Properties." In Reservoir Model Design, 115–49. Dordrecht: Springer Netherlands, 2014. http://dx.doi.org/10.1007/978-94-007-5497-3_4.

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Lucia, F. Jerry. "Petrophysical Rock Properties." In Carbonate Reservoir Characterization, 1–22. Berlin, Heidelberg: Springer Berlin Heidelberg, 1999. http://dx.doi.org/10.1007/978-3-662-03985-4_1.

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Ringrose, Philip, and Mark Bentley. "Upscaling Flow Properties." In Reservoir Model Design, 131–64. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-70163-5_4.

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Tate, Naoya. "Quantum-Dot-Based Photonic Reservoir Computing." In Photonic Neural Networks with Spatiotemporal Dynamics, 71–87. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-5072-0_4.

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AbstractReservoir computing is a novel computational framework based on the characteristic behavior of recurrent neural networks. In particular, a recurrent neural network for reservoir computing is defined as a reservoir, which is implemented as a fixed and nonlinear system. Recently, to overcome the limitation of data throughput between processors and storage devices in conventional computer systems during processing, known as the Von Neumann bottleneck, physical implementations of reservoirs have been actively investigated in various research fields. The author’s group has been currently studying a quantum dot reservoir, which consists of coupled structures of randomly dispersed quantum dots, as a physical reservoir. The quantum dot reservoir is driven by sequential signal inputs using radiation with laser pulses, and the characteristic dynamics of the excited energy in the network are exhibited with the corresponding spatiotemporal fluorescence outputs. We have presented the fundamental physics of a quantum dot reservoir. Subsequently, experimental methods have been introduced to prepare a practical quantum dot reservoir. Next, we have presented the experimental input/output properties of our quantum dot reservoir. Here, we experimentally focused on the relaxation of fluorescence outputs, which indicates the characteristics of optical energy dynamics in the reservoir, and qualitatively discussed the usability of quantum dot reservoirs based on their properties. Finally, we have presented experimental reservoir computing based on spatiotemporal fluorescence outputs from a quantum dot reservoir. We consider that the achievements of quantum dot reservoirs can be effectively utilized for advanced reservoir computing.
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Lucia, F. Jerry. "Erratum to: Petrophysical Rock Properties." In Carbonate Reservoir Characterization, 227. Berlin, Heidelberg: Springer Berlin Heidelberg, 1999. http://dx.doi.org/10.1007/978-3-662-03985-4_9.

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Archer, J. S., and C. G. Wall. "Properties of Reservoir Fluids." In Petroleum Engineering, 40–61. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_4.

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Pedersen, Karen Schou, Peter Lindskou Christensen, and Jawad Azeem Shaikh. "Transport Properties." In Phase Behavior of Petroleum Reservoir Fluids, 275–310. 3rd ed. Boca Raton: CRC Press, 2023. http://dx.doi.org/10.1201/9780429457418-10.

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Conference papers on the topic "Reservoir properties"

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Aubert-Kato, Nathanael, and Mika Ito. "Exploration of Reservoir Properties in Molecular Computing Systems." In 2024 IEEE Congress on Evolutionary Computation (CEC), 1–8. IEEE, 2024. http://dx.doi.org/10.1109/cec60901.2024.10612038.

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Collett, Timothy S. "Gas Hydrate Reservoir Properties." In Unconventional Resources Technology Conference. Society of Exploration Geophysicists, American Association of Petroleum Geologists, Society of Petroleum Engineers, 2013. http://dx.doi.org/10.1190/urtec2013-197.

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Urosevic, M., S. Amiri Besheli, S. S. Hendi, and J. Vali. "LMR – A Robust Reservoir Properties Indicator in Carbonate Reservoirs." In 66th EAGE Conference & Exhibition. European Association of Geoscientists & Engineers, 2004. http://dx.doi.org/10.3997/2214-4609-pdb.3.p161.

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Helwick, S. J., M. L. Porter, R. S. Hubbard, K. Bhuyhan, C. S. Calvert, K. E. Dahlberg, V. Khare, N. C. Lian, E. J. Oswald, and L. A. Wahrmund. "Geostatistical reservoir modeling integrating seismically derived reservoir properties." In SEG Technical Program Expanded Abstracts 1994. Society of Exploration Geophysicists, 1994. http://dx.doi.org/10.1190/1.1822880.

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Hewett, Thomas A., and Rosalind A. Archer. "Scale-Averaged Effective Flow Properties for Coarse-Grid Reservoir Simulation." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/37988-ms.

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Poe, B. D. "Evaluation of Reservoir and Hydraulic Fracture Properties in Geopressure Reservoirs." In International Oil and Gas Conference and Exhibition in China. Society of Petroleum Engineers, 2000. http://dx.doi.org/10.2118/64732-ms.

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Morte, Matthew, Hasan Alhafidh, and Berna Hascakir. "Sensitivity of Dielectric Properties to Varying Reservoir Properties." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/201371-ms.

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Lee, Tai-yong, and John Seinfeld. "Estimation of petroleum reservoir properties." In 26th IEEE Conference on Decision and Control. IEEE, 1987. http://dx.doi.org/10.1109/cdc.1987.272638.

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Couples, G. D., H. Lewis, M. A. Reynolds, G. E. Pickup, J. Ma, M. Rouainia, N. Bicanic, and C. J. Pearce. "Upscaling Fluid-Flow and Geomechanical Properties in Coupled Matrix+Fractures+Fluids Systems." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2003. http://dx.doi.org/10.2118/79696-ms.

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Jin, Long, Paul Stoffa, and Mrinal Kanti Sen. "Stochastic Reservoir Properties Inversion Using Parallel Learning Based VFSA and Pilot Point Parameterization." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/118818-ms.

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Reports on the topic "Reservoir properties"

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Nur, Amos. Porous reservoir rocks with fluids: Reservoir transport properties and reservoir conditions. Office of Scientific and Technical Information (OSTI), January 2004. http://dx.doi.org/10.2172/820852.

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Roberts, J., B. P. Bonner, and A. Duba. Electrical properties of SB-15D rocks at reservoir conditions. Office of Scientific and Technical Information (OSTI), August 1996. http://dx.doi.org/10.2172/443991.

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Cook, N. G. W. Geophysical and transport properties of reservoir rocks. Summary annual report. Office of Scientific and Technical Information (OSTI), April 1990. http://dx.doi.org/10.2172/10170863.

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Cook, N. G. W. Geophysical and transport properties of reservoir rocks. Final report for task 4: Measurements and analysis of seismic properties. Office of Scientific and Technical Information (OSTI), May 1993. http://dx.doi.org/10.2172/10159675.

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Oliver, Dean S., Albert C. Reynolds, Fengjun Zhang, Ruijian Li, Yafes Abacioglu, and Yannong Dong. Mapping of Reservoir Properties and Facies Through Integration of Static and Dynamic Data. Office of Scientific and Technical Information (OSTI), March 2002. http://dx.doi.org/10.2172/792248.

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Reynolds, Albert C., Dean S. Oliver, Fengjun Zhang, Yannong Dong, Jan Arild Skjervheim, and Ning Liu. Mapping of Reservoir Properties and Facies Through Integration of Static and Dynamic Data. Office of Scientific and Technical Information (OSTI), March 2003. http://dx.doi.org/10.2172/808645.

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Albert C. Reynolds, Dean S. Oliver, Yannong Dong, Ning Liu, Guohua Gao, Fengjun Zhang, and Ruijian Li. MAPPING OF RESERVOIR PROPERTIES AND FACIES THROUGH INTEGRATION OF STATIC AND DYNAMIC DATA. Office of Scientific and Technical Information (OSTI), December 2004. http://dx.doi.org/10.2172/837887.

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Albert C. Reynolds, Dean S. Oliver, Fengjun Zhang, Yannong Dong, Jan Arild Skjervheim, and Ning Liu. MAPPING OF RESERVOIR PROPERTIES AND FACIES THROUGH INTEGRATION OF STATIC AND DYNAMIC DATA. Office of Scientific and Technical Information (OSTI), January 2003. http://dx.doi.org/10.2172/820625.

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BACKHOUSE, Lorna, Vasily DEMYANOV, and Mike CHRISTIE. Integrating prior knowledge through multiple kernel learning for the prediction of petroleum reservoir properties. Cogeo@oeaw-giscience, September 2011. http://dx.doi.org/10.5242/iamg.2011.0264.

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Larmagnat, S., P. Francus, M. Des Roches, L. F. Daigle, J. Raymond, M. Malo, and A. Aubiès-Trouilh. Tomodensitometry applied to characterize rock properties of a conventional heterogeneous carbonate reservoir in Quebec. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2018. http://dx.doi.org/10.4095/308112.

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