To see the other types of publications on this topic, follow the link: Reservoir properties.
Dissertations / Theses on the topic 'Reservoir properties'
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the top 50 dissertations / theses for your research on the topic 'Reservoir properties.'
Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.
You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.
Browse dissertations / theses on a wide variety of disciplines and organise your bibliography correctly.
1
AlBinHassan, Nasher M. "Reservoir properties prediction in carbonate reservoirs." Thesis, Imperial College London, 2010. http://hdl.handle.net/10044/1/5922.
Full textAbstract:
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.
2
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.
Full text
3
Yang, Huade. "Relationships between petrophysical properties and petrographic properties of reservoir rocks /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.
Full text
4
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.
Full text
5
Han, Tongcheng. "Joint elastic-electrical properties of reservoir sandstones." Thesis, University of Southampton, 2010. https://eprints.soton.ac.uk/195017/.
Full textAbstract:
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.
6
Li, Xuesong. "Interfacial properties of reservoir fluids and rocks." Thesis, Imperial College London, 2013. http://hdl.handle.net/10044/1/14380.
Full textAbstract:
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.
7
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.
Full textAbstract:
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.
8
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.
Full text
9
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.
Full text
10
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.
Full text
11
Seifert, Dirk. "Uncertainties in spatial modelling of static reservoir properties." Thesis, Heriot-Watt University, 1997. http://hdl.handle.net/10399/673.
Full text
12
Oloso, Munirudeen Ajadi. "Prediction of reservoir fluid properties using machine learning." Thesis, University of Portsmouth, 2018. https://researchportal.port.ac.uk/portal/en/theses/prediction-of-reservoir-fluid-properties-using-machine-learning(a0f121e7-9e87-468d-a001-42ddb9d5a421).html.
Full textAbstract:
The phase and volumetric behaviour of reservoir fluid properties, referred to as pressure-volumetemperature (PVT) properties, involve the thermodynamic studies of the fluid with respect to pressure, temperature and its volumetric compositions. PVT properties are usually determined by laboratory experiments performed on the actual samples of the reservoir fluid. Failing that, these fluid properties have been evaluated by some other methods such as equations of state, empirical correlations and recently, machine learning models. Machine learning is basically the prediction of the future with, (supervised learning), or without, (unsupervised learning), prior knowledge of the past. A common problem for the standalone machine learning technique is local minimum. In view of this, ensemble systems and hybrid techniques have been developed successfully for improvement in different fields. This work introduces two different ensemble methods based on support vector regression and regression trees where both ensemble approaches utilise a novel concept tagged "Tying Ranking" in selection of the base models. Also, a hybrid system for reservoir fluid characterisation with a novel way of grouping petroleum fluid properties using intelligent method was developed. The hybrid system uses K-Means clustering for the intuitive grouping along with functional networks for the prediction. The performance and generalisation of the developed models are compared against their standalone and selected empirical models using some statistical measures which are commonly used for performance evaluation in the petroleum industry. In the first category of experimentation, the impact and effect of training the machine learning models with more diverse and bigger data set is shown. Effects of using different functional forms to predict dead oil, saturated and undersaturated viscosity are also explored. In addition, impacts of different statistical measures on the predicted outputs and wrong interpretations of results in the literature are examined. The main statistical measures that are used for comparison are root mean squared errors, average absolute percentage relative error and maximum absolute percentage relative error. For each of the reservoir fluid properties considered in this work, at least one or more of the developed machine learning models have better overall and average performance than all the compared correlations in each category. The superiority of the three developed machine learning models is visible in the trend analysis as they show less deviations in results compared to the empirical correlations and their standalone methods in most cases for all the considered reservoir fluid properties.
13
Al-Bulushi, Nabil. "Predicting reservoir properties using artificial neural networks (ANNs)." Thesis, Imperial College London, 2008. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.498402.
Full text
14
Srinivasan, Balaji S. "The impact of reservoir properties on mixing of inert cushion and natural gas in storage reservoirs." Morgantown, W. Va. : [West Virginia University Libraries], 2006. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4653.
Full textAbstract:
Thesis (M.S.)--West Virginia University, 2006.Title from document title page. Document formatted into pages; contains vii, 88 p. : ill. (some col.), map (part col.). Includes abstract. Includes bibliographical references (p. 47-49).
15
Castoro, Alessandro. "Mapping reservoir properties through pre-stack seismic attribute analysis." Thesis, Birkbeck (University of London), 1999. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.327052.
Full text
16
Sharp, Andrew James. "Seismic properties of reservoir rocks from the Morecambe Bay gas fields." Thesis, University of Reading, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.298578.
Full text
17
Calleja, Glecy School of Biological Earth & Environmental Sciences UNSW. "Influence of mineralogy on petrophysical properties of petroleum reservoir beds." Awarded by:University of New South Wales. School of Biological, Earth and Environmental Sciences, 2005. http://handle.unsw.edu.au/1959.4/22423.
Full textAbstract:
Key petrophysical properties of reservoir sequences are determined by their individual mineral compositions, and are routinely evaluated through the analysis of cores and geophysical well logs. However, mineralogical studies are seldom incorporated in reservoir assessment. The objectives of the study were to investigate the influence of mineralogy on petrophysical properties of petroleum reservoir beds and the application of mineralogical studies in reservoir evaluation. Mineralogical analyses were performed on core samples from the Plover Formation, the principal reservoir sequence in the Northwest Shelf area of Australia, intersected in two separate wells in the Laminaria petroleum field. The techniques used included X-ray powder and oriented-aggregate analysis, optical microscopy and whole rock geochemistry. Quantification of each mineral phase based on whole-rock powder data was performed using the Rietveld-based Siroquant technique. Results from the Siroquant assay were used as an indicator of mineralogy for the individual samples and were compared with core plug and geophysical log data. X-ray micro-tomography analysis of selected samples was also performed. The reservoir sequences in both wells were sand-dominated, consisted mostly of quartz, clay mineral matrix and cement of silica, pyrite or calcite. The abundance of clay minerals increased in the shale and shaly sandstone intervals. Comparison of mineralogical and core plug analyses of samples from the same depths showed that the down-hole variations in porosity, permeability, grain density and radioactivity were accompanied by changes in mineralogy. Higher proportion of clay minerals in shales was indicated by higher gamma log signals. The gamma log may be taken as an indicator of shaliness only in intervals where kaolinite is proportional to the quantity of illitic clays. Sonic log and neutron log porosity values are comparable with core plug porosity data in sandstone intervals. However, clay minerals increase the sonic log response, thereby increasing porosity in shaly intervals. Clay minerals tend to decrease the neutron log response causing higher porosity indication in shales, similar to that expected in sandstones. Routine density log analysis underestimated porosity values because of the contribution of dense minerals to the bulk density of the formation. Use of laboratory determined grain and fluid densities resulted in improved density log porosity compared to core porosity. X-ray tomography analysis revealed an overall positive correlation between mineralogy and porosity data. Routine geophysical log evaluation revealed inconsistent results when compared to core analysis data because of the influence of minerals on various logs. It is essential that mineralogical studies be included in reservoir assessment. X-ray tomography may provide an alternative approach in evaluating porosity and mineralogy.
18
Arns, Christoph Hermann Petroleum Engineering Faculty of Engineering UNSW. "The influence of morphology on physical properties of reservoir rocks." Awarded by:University of New South Wales. Petroleum Engineering, 2002. http://handle.unsw.edu.au/1959.4/18257.
Full textAbstract:
We consider the structural and physical properties of complex model morphologies and microstructures obtained by Xray-CT imaging. The Minkowski functionals, a family of statistical measures based on the Euler-Poincaré characteristic of n-dimensional space, are shown to be sensitive measures of the morphology of disordered structures. Analytic results for the Boolean model are given and used to devise a reconstruction scheme, which allows one to accurately reconstruct a complex Boolean structure given at any phase fraction for all other phase fractions. The percolation thresholds of either phase are obtained with good accuracy. From the reconstructions one can subsequently predict property curves for the material across all phase fractions from a single 3D image. We illustrate this for transport and mechanical properties of complex Boolean systems and for experimental sandstone samples. By extending the Minkowski functionals to parallel surfaces using operations from mathematical morphology, a powerful discrimination of structure is obtained. Further the sensitivity of the Minkowski functionals under experimental conditions is analysed. Accurate calculations of conductive and elastic properties directly from tomographic images are achieved by estimating and minimising several sources of numerical error. Simulations of electrical conductivity and linear elastic properties on microtomographic images of Fontainebleau sandstone are in excellent agreement with experimental measurements over a wide range of porosity. The results show the feasibility of combining digitised images with transport and elasticity calculations to accurately predict physical properties of individual material morphologies. We show that measurements of properties based on microtomographic images are more accurate than those based on conventional theories for disordered materials. We study the elastic behaviour of model clean and cemented sandstones. Results are in excellent agreement with available experimental data, and are compared to conventional theoretical and empirical laws. A new predictive empirical method is given for predicting the elastic moduli of sandstone morphologies. The method gives an excellent match to numerical and experimental data.
19
Chow, Yu Tsing Florence. "Interfacial properties of reservoir fluids and carbon dioxide with impurities." Thesis, Imperial College London, 2016. http://hdl.handle.net/10044/1/44376.
Full textAbstract:
Interfacial tension measurements of the binary systems (N2 + H2O), (Ar + H2O), and (H2 + H2O), and ternary systems (CO2 + N2 + H2O), (CO2 + Ar + H2O) and (CO2 + H2 + H2O), are reported at pressures of (0.5 to 50.0) MPa, and temperatures of (298.15 to 473.15) K. The design of a custom-built Interfacial Properties Rig was detailed. The pendant drop method was used. The expanded uncertainties at 95% confidence are 0.05 K for temperature; 0.07 MPa for pressure; 0.019·γ for interfacial tension in the (N2 + H2O) system; 0.016·γ for interfacial tension in the (Ar + H2O) system; 0.017·γ for interfacial tension in the (H2 + H2O) system; 0.032·γ for interfacial tension in the (CO2 + N2 + H2O) system; 0.018·γ for interfacial tension in the (CO2 + Ar + H2O) system; and 0.017·γ for interfacial tension in the (CO2 + H2 + H2O) system. The interfacial tensions of all systems were found to decrease with increasing pressure. The use of SGT + SAFT-VR Mie to model interfacial tensions of the binary and ternary systems was reported, for systems involving CO2, N2 and Ar. The binary systems (N2 + H2O) and (Ar + H2O), and ternary systems (CO2 + N2 + H2O) and (CO2 + Ar + H2O), were modelled with average absolute relative deviations of 1.5 %, 1.8 %, 3.6 % and 7.9 % respectively. For the (CO2 + Ar + H2O) system, the agreement is satisfactory at the higher temperatures, but differs significantly at the lower temperatures. Contact angles of (CO2 + brine) and (CO2 + N2 + brine) systems on calcite surfaces have also been measured, at 333 K and 7 pressures, from (2 to 50) MPa, for a 1 mol·kg-1 NaHCO3 brine solution, using the static method on captive bubbles.
20
Abdelkarim, Omar A. "Rheological and flow resistance properties of EOR polymers in reservoir rocks /." Electronic version of summary, 1991. http://www.wul.waseda.ac.jp/gakui/gaiyo/1666.pdf.
Full text
21
Idris, Ahmad Kamal Bin. "Some effects of wettability and fluid properties on immiscible displacement in porous media." Thesis, Imperial College London, 1990. http://hdl.handle.net/10044/1/11384.
Full text
22
Erdogan, Sinem Setenay. "A Preliminary Study On The Use Of Reservoir Simulation And Coal Mine Ventilation Methane Measurements In Determining Coal Reservoir Properties." Master's thesis, METU, 2011. http://etd.lib.metu.edu.tr/upload/12613047/index.pdf.
Full textAbstract:
This thesis investigates methane emissions and methane production potentials from abandoned longwall panels produced or emitted due to mining activities either from coal seam or any underlying or overlying formations. These emissions can increase greenhouse gas concentrations and also pose a danger to the underground working environment and to miners. In addition to the safety issues, recovery and utilization of this gas is an additional source of energy.
In this study, methane concentrations measured from ventilation air ways in Yeni Çeltek Coal Mine, which is located in Suluova basin, Amasya, and contains thick, laterally extensive Lower Eocene coal seams, were integrated within a numerical vi reservoir model. Key reservoir parameters for history matching are cleat permeabilities, cleat porosity, diffusion time and Langmuir volume and Langmuir pressure. Thirteen cases were studied. According to the results, Case-10 determined as the best fitted case for both of the production wells. Cleat permeabilities and Langmuir pressure were the most effective parameters. Reservoir parameters matched are cleat permeabilities of 5, 4 and 1 md and fracture dimensions of 0.8, 0.4, and 0.1 m in x, y and z direction respectively, 2 % cleat porosity, 0.3 % water saturation. Diffusion time was determined as 400 days and 2000 kPa Langmuir volume and 6.24279 m3 /tone gas content estimated. According to these results it can be said that methane production will not be economically feasible, however
to remedy underground working conditions and safety of workers methane management should be taken into consideration.
23
Tao, Guo. "Acoustic wave velocities, attenuation and transport properties of some sandstones." Thesis, Imperial College London, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.319154.
Full text
24
Prater, Tanita. "Comparison of rock-type-derived reservoir properties with estimates from standard petrography /." Title page, contents and abstract only, 1999. http://web4.library.adelaide.edu.au/theses/09S.B/09s.bp912.pdf.
Full text
25
Best, Angus Ian. "The prediction of the reservoir properties of sedimentary rocks from seismic measurements." Thesis, University of Reading, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.331984.
Full textAbstract:
Recent technological advances have led to dramatic improvements in seismic resolution which now enable seismic attenuation to be measured on a routine basis. The usefulness of seismic attenuation as an interpretation parameter is restricted at present by our incomplete knowledge of the relationships between attenuation and important reservoir parameters such as porosity, permeability and the nature of the pore fluid. In order to redress this imbalance, P-wave and S-wave velocities and attenuations were measured in the laboratory at a frequency of about 0.8 MHz and at an effective pressure of 60 MPa on a set of reservoir rocks comprising twenty-seven shaly sandstones and two sandy shales. It was discovered that both P-wave and Swave attenuation increase with increasing percentage of intrapore minerals (especially clay, but also micrite) from the composition of a clean sandstone to a value of 50%, and then they decrease with increasing clay content as the rock approaches the composition of a pure shale. Porosity plays a subsidiary role to pore fill. More work is needed to predict permeability from its complex relationships with porosity and pore filling minerals. Ultrasonic P-wave and S-wave velocities (Vp and Vs) were shown to be strongly dependent on the amount of pore fill: velocity is reduced by increasing amounts of clays and micrite, but it is increased by increasing amounts of sparry calcite cement. Contrary to popular understanding, the effect on velocity of the percentage of pore filling minerals is much stronger than that of porosity on velocity, although porosity is still an important parameter. There is a strong correlation between Vp and Vs, and between P-wave quality factor (Qp) and S-wave quality factor (Qs). Interesting relationships were also discovered between Qp and Vp, and especially between Qs and Vs. However, high frequency laboratory measurements may not be representative of the low frequencies used in seismic exploration. The frequency dependence of velocity and attenuation in reservoir sandstones was investigated by exploiting the inverse relationship between frequency and pore fluid viscosity predicted by the Biot theory. P-wave and S-wave velocities and attenuations were measured at a frequency of about 0.8 MHz and at an effective pressure of 50 MPa on shaly sandstones saturated with pore fluids of viscosities 0.3 cP to 1000 cP (equivalent frequency range 2.6 MHz to 780 Hz). The Biot theory accounts for the very high Q values encountered in clean sandstones, but not the very low Q values observed in clay-rich sandstones. The observed velocity dispersion in both clean and clay-rich sandstonesim plies a local fluid flow mechanism which predicts the opposite frequency-viscosity dependence of the Biot theory. Qp and Qs in clay-rich sandstones remain constant over nearly four decades in equivalent frequency. This implies a range of relaxation times which may be attributed to the wide distribution of pore sizes of clays and other pore filling minerals. Moreover, this constant Q behaviour and the magnitude of the laboratory Qp and Qs values tie in well with those obtained from field studies. This suggests that Qp and Qs are broadly independent of frequency from seismic frequencies to ultrasonic frequencies in clay-rich sandstones.
26
Busch, Benjamin [Verfasser]. "Impact of grain coats on quartz overgrowth and Reservoir properties / Benjamin Busch." Karlsruhe : KIT Scientific Publishing, 2017. http://www.ksp.kit.edu.
Full text
27
Wojtacki, Kajetan Tomasz. "Coupling between transport, mechanical properties and degradation by dissolution of rock reservoir." Thesis, Montpellier, 2015. http://www.theses.fr/2015MONTS153/document.
Full textAbstract:
L'objectif de cette thèse est d'analyser l'évolution des propriétés mécaniques et de transport effectives de roches aquifères,qui sont soumises à une dégradation progressive par attaque chimique due à la dissolution par CO2.L'étude proposée porte sur les conditions à long terme et en champ lointain, lorsque la dégradation de la matrice poreuse peut être supposée homogène à l'échelle de l'échantillon.La morphologie du réseau de pores et du squelette solide définissant les propriétés macroscopiques majeures de la roche (perméabilité, élasticité),la modélisation d'un tel matériau poreux doit être basée sur une caractérisation morphologique et statistique des roches étudiées.Tout d'abord, une méthode de reconstruction inspirée du processus naturel de formation des grès est développée afin d'obtenir des représentations statistiquement équivalentes à de véritables échantillons.Les échantillons générés sont sélectionnés afin de satisfaire les informations morphologiques extraites de l'analyse des images microtomographiques d'échantillons de roche naturelle.Une méthodologie afin d'estimer les propriétés mécaniques équivalentes des échantillons générés, fondées directement sur des maillages réguliers considérés comme images binaires, est présentée.Le comportement mécanique équivalent est obtenu dans le cadre de l'homogénéisation périodique.Mais en raison du manque de périodicité géométrique des échantillons considérés, deux approches différentes sont développées :la reconstruction de VER par symétrie de réflexion ou l'addition d'une couche homogène associée à une méthode de point fixe.L’évolution de la perméabilité est estimée de manière classique en utilisant la méthode de mise à l'échelle dans la forme de la loi de Darcy. Enfin, la dissolution chimique du matériau est abordée par dilatation morphologique de la phase poreuse.De plus, une analyse détaillée de l'évolution des descripteurs morphologiques liée aux modifications de la microstructure lors des étapes de dissolution est présentée.La relation entre les propriétés morphologiques - perméabilité - modules d'élasticité est également fournie.La méthodologie développée dans ce travail pourra être facilement appliquée à d'autres classes de matériaux hétérogènesThe aim of this thesis is to analyse evolution of effective mechanical and transport properties of rock aquifer, which is subjected to progressive chemical degradation due to CO2 dissolution. The proposed study focuses on long-term and far field conditions, when degradation of porous matrix can be assumed to be homogeneous at sample scale. It is very well known that morphology of pore network and solid skeleton defines important macroscopic properties of the rock (permeability, stiffness). Therefore, modelling of such porous material should be based on morphological and statistical characterisation of investigated rocks. First of all, in order to obtain statistically equivalent representations of real specimen a reconstruction method inspired by natural process of sandstone formation is adapted. Then the selected generated samples satisfy morphological informations which are extracted by analysing microtomography of the natural rock sample. Secondly, a methodology to estimate effective mechanical properties of investigated material, based directly on binary images, is featured. Effective mechanical behaviour is obtain within the framework of periodic homogenization, However due to lack of geometrical periodicity two different approaches are used (reflectional symmetry of considered RVE and a fixed point method, using additional layer spread over the considered geometry). Evolution of permeability is estimated in classical way using upscaling method in the form of Darcy's law. Finally, chemical dissolution of material is tackled in a simplified way by performing morphological dilation of porous phase. Detailed analysis of chosen morphological descriptors evolution, triggered by modifications of microstructures is provided. The relation between morphological properties – permeability – elastic moduli is also provided. The methodology developed in this work could be easily applied to other heterogeneous materials
28
Li, Pui-Wa. "Investigation of sensitivity of surface deformation to subsurface properties and reservoir operations." Thesis, Massachusetts Institute of Technology, 2012. http://hdl.handle.net/1721.1/74466.
Full textAbstract:
Thesis (S.M.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, 2012.Cataloged from PDF version of thesis.
Includes bibliographical references (p. 60).
An experimental study is performed to understand the sensitivity of ground deformation to subsurface properties and operations of oil and gas fields. Ground deformation, or more severely subsidence, may pose concerns for human settlements situated above the reservoir. This Masters thesis will study a realistic sample problem on its surface deformation sensitivity, in hopes of providing a sound basis for future characterization of subsurface properties and the forecast of surface deformation due to oil and gas production. Iteratively coupled simulations are performed to test how sensitive the surface deformation is to changing subsurface parameters. To test the validity of such coupled simulator, comparison of the displacement results with those of another commercially available software is also carried out. Results show that the change of surface displacement particularly in the vertical direction tends to be within the range of detection of satellites, of which data will serve as the input of future inversions with the Ensemble Kalman Filter (EnKF).
by Pui-Wa Li.
S.M.
29
Jaafar, Mohammed Dhia. "The development of simulation and analytical models to evaluate tight zone/barrier properties from vertical interference testing." Thesis, Heriot-Watt University, 1989. http://hdl.handle.net/10399/954.
Full text
30
Pandey, Rohit. "Changes in properties of coal as a result of continued bioconversion." OpenSIUC, 2015. https://opensiuc.lib.siu.edu/theses/1745.
Full textAbstract:
Microbial actions on coal have long been identified as a source of methane in coalbeds. Andrew Scott (1995) was the first to propose imitating the natural process of biogenic gasification, possibly leading to recharging coalbed methane (CBM) reservoirs, or setting up natural gas reservoirs in non-producing coalbeds. This study was aimed at identifying the changes in coal properties that affect gas deliverability in coal-gas reservoirs, when treated with microbial consortia to generate/enhance gas production. The experimental work tested the sorption and diffusion properties for the coal treated and, more importantly, the variation in the relevant parameters with continued bio-conversion since these are the first two phenomena in CBM production. During the first phase, single component sorption-diffusion experiments were carried out using pure methane and CO2 on virgin/baseline coals, retrieved from the Illinois basin. Coals were then treated with nutrient amended microbial consortia for different periods. Gas production was monitored at the end of thirty and sixty days of treatment, after which, sorption-diffusion experiments were repeated on treated coals, thus establishing a trend over the sixty-day period. The sorption data was characterized using Langmuir pressure and volume constants, obtained by fitting it over the Langmuir isotherm. The diffusion coefficient, D, was estimated by establishing the variation trend as a function of pore pressure. The pressure parameter was considered critical since, with continued production of methane, the produced gas diffuses into the coal matrix, where it gets adsorbed with increasing pressure. During production, the pressure decreases and the process is reversed, gas diffusing out of the coal matrix and arriving at the cleat system. The results indicated an increase in the sorption capacity of coal as a result of bioconversion. This was attributed to increased pore surface areas as a result of microbial actions. However, significant hysteresis was observed during desorption of methane and was attributed to preferential desorption from sorption sites in the pathways leading to pore cavities. This is corroborated by the increased rates of diffusion, especially for methane, which exhibited rates higher than that for CO2. This contradicted the results for untreated/baseline coal, which were in agreement with previous studies. Effort was made to explain this anomaly by the non-monotonic dependence of effective diffusion coefficient on the size of the diffusing particles, where in coalbed environments, CO2 has smaller kinetic diameter than methane.
31
Edlmann, Katriona. "A new methodology for predicting the geo-mechanical properties of clastic reservoir rocks." Thesis, Heriot-Watt University, 2001. http://hdl.handle.net/10399/507.
Full text
32
Saggaf, Muhammad M. "An integrated seismic and well log analysis for the estimation of reservoir properties." Thesis, Massachusetts Institute of Technology, 2000. http://hdl.handle.net/1721.1/8852.
Full textAbstract:
Thesis (Ph.D.)--Massachusetts Institute of Technology, Dept. of Earth, Atmospheric, and Planetary Sciences, 2000.Includes bibliographical references (p. 391-399).
We present an integrated approach for characterizing the reservoir and estimating its properties both at the well locations and in the inter-wen regions. Such an approach can be an invaluable tool for attaining a detailed, consistent, and complete characterization of the reservoir, as not only does it incorporate all major sources of information that shape our understanding of the reservoir, including core descriptions, well Jogs, seismic data, and a priori knowledge of the geological setting of the region, but also it develops means for utilizing these sources of information in a unified manner that gives rise to a coherent framework for relating these sources of information to yield an integrated reservoir model. We analyze the different components of this approach, develop methodologies for improving the prediction accuracy of each, and link the mechanisms across these components to achieve an accurate and consistent characterization of the reservoir. The issues we tackle in this thesis can be broadly divided into four categories: enhancement of the seismic resolution, estimation of the reservoir properties at the well locations, characterizing the reservoir in the inter-well regions, and pre-processing the data to remedy any incompleteness or inconsistency.
by Muhammad M. Saggaf.
Ph.D.
33
Al, Ghafri Saif. "Phase behaviour and physical properties of reservoir fluids under addition of carbon dioxide." Thesis, Imperial College London, 2014. http://hdl.handle.net/10044/1/19007.
Full textAbstract:
The phase behaviour of reservoir fluids under the addition of carbon dioxide (CO2) were studied at elevated pressures and temperatures similar to those encountered in enhanced oil recovery (EOR) and carbon storage processes. The principal focus of the work presented in this thesis is the experimental investigation of the phase behaviour of these CO2 mixtures with hydrocarbon reservoir fluids. For this purpose, a new high-pressure high-temperature apparatus was designed and constructed. The apparatus consisted of a thermostated variable-volume view cell driven by a computer-controlled servo motor system. The maximum operating pressure and temperature were 40 MPa and 473.15 K, respectively. Measurements were then made over a wide range of pressure and temperature conditions for two representative CO2-hydrocarbon systems: (CO2 + n-heptane + methylbenzene) and (CO2 + synthetic crude oil). The vapour-liquid phase behaviour of the former system was studied, under CO2 addition and various molar ratios of n-heptane to methylbenzene, along different isotherms at temperatures between (298 and 473) K and at pressures up to approximately 16 MPa. In the latter, the synthetic oil contained a total of 17 components while solution gas (methane, ethane and propane) was added to obtain live synthetic crudes with gas-oil ratios of either 58 or 160. Phase equilibrium and density measurements were then made for the ‘dead’ oil and the two ‘live’ oils under the addition of CO2. The measurements were carried out at temperatures between (298.15 and 423.15) K and at pressures up to 36 MPa, and included vapour-liquid, liquid-liquid and vapour-liquid-liquid equilibrium conditions. The phase equilibria of (carbon dioxide + n-heptane + water) and (carbon dioxide + methane + water) mixtures were also studied using a high pressure quasi-static analytical apparatus with on-line compositional analysis by gas chromatography. The former system was studied under conditions of three-phase equilibria along five isotherms at temperatures from (323.15 to 413.15) K and at pressures up to the upper critical end point (UCEP). In the latter system, compositions of three coexisting fluid phases have been obtained along eight isotherms at temperatures from (285.15 to 303.5) K and at pressures up to either the UCEP or up to the hydrate formation locus. Compositions of coexisting vapour and liquid phases have been obtained along three isotherms at temperatures from (323.15 to 423.15) K and pressures up to 20 MPa for mixtures containing nearly equal overall mole fractions of CH4 and CO2. The quadruple curve along which hydrate coexists with the three fluid phases was also measured. A detailed study of these ternary mixtures was carried out based on comparison with available ternary data of the type (CO2 + n-alkane + water) and available data for the constituent binary subsystems. In this way, we analyze the observed effects on the solubility when the n-alkane component was changed or a third component was added. The experimental data for the (CO2 + hydrocarbon) systems have been compared with results calculated with two predictive models, PPR78 and PR2SRK, based on Peng-Robinson 78 (PR78) and Soave-Redlich-Kwong (SRK) cubic equations of state (EoS) with group-contribution formula for the binary interaction parameters and with the use of different alpha functions. Careful attention was paid to the critical constants and acentric factor of high molar-mass components. The use of the Boston-Mathias modification of the PR78 and SRK equations was also investigated. The experimental data obtained for the (CO2 + n-heptane + methylbenzene) mixture were also compared with the predictions made using SAFT-Gamma-Mie, a group-contribution version of the Statistical Associating Fluid Theory (SAFT), which was implemented with the generalized Mie potential to represent segment-segment interactions. Detailed assessment of the predictive capability of these models concluded that the agreement between the experimental data and prediction from these methods, while not perfect, is very good, especially on the bubble curve. The results suggest that there is merit in the approach of combining these methods with a group-contribution scheme. Comparison between these approaches concluded that they all have comparable accuracies regarding VLE calculations. The experimental data obtained for the ternary mixtures (CO2 + n-alkane + water) have been compared with the predictions of SAFT for potentials of variable range (SAFT-VR), implemented with the square-well (SW) potential using parameters fitted to experimental pure-component and binary-mixture data. A good performance of the SAFT-VR equation in predicting the phase behaviour at different temperatures was observed even with the use of temperature-independent binary interaction parameters. It was also observed that an accurate prediction of phase behaviour at conditions close to criticality cannot be accomplished by mean-field based theories, such as the models used in this work, that do not incorporate long-range density fluctuations. Density measurements on a variety of brines (both single-salt and mixed) were studied in the present work within the context of CO2 storage processes in saline aquifers. Densities of MgCl2(aq), CaCl2(aq), KI(aq), NaCl(aq), KCl(aq), AlCl3(aq), SrCl2(aq), Na2SO4(aq), NaHCO3(aq) , the mixed salt system [(1 – x) NaCl + xKCl](aq) and the synthetic reservoir brine system [x1NaCl + x2KCl + x3MgCl2 + x4CaCl2 + x5SrCl2 + x6Na2SO4 + x7NaHCO3](aq), where x denotes mole fraction, were studied at temperatures between (283 and 473) K and pressures up to 68.5 MPa. The measurements were performed with a vibrating-tube densimeter calibrated under vacuum and with pure water over the full ranges of pressure and temperature investigated. It was observed that careful attention needs to be paid to the type of calibration method selected. An empirical correlation is reported that represents the density for each brine system as a function of temperature, pressure and molality with absolute average relative deviations (%AAD) of approximately 0.02 %. Comparing the model with a large database of results from the literature suggested that the model is in good agreement with most of the available data. The model can be used to calculate density, apparent molar volume and isothermal compressibility of single component salt solutions over the full ranges of temperature, pressure and molality studied. An ideal mixing rule for the density of a mixed electrolyte solution was tested against our mixed salts data and was found to offer good predictions at all conditions studied with an absolute average relative deviation of 0.05 %. The present work was carried out as part of the Qatar Carbonates and Carbon Storage Research Centre (QCCSRC) program. It covered a wide range of phase behaviour and density measurements at conditions relevant to oil and gas fields’ applications, and explored the predictive capabilities of some available models, in particular predictive cubic EoS, SAFT-VR and SAFT-Gamma-Mie. The research and data collected represents a good step in enabling the direct design and optimisation of CO2-EOR and carbon storage processes. An example is the validation of the predictive models and the determination of the miscibility pressure which is essential for effective recovery of the heavy hydrocarbons. Areas in which the research might be extended, both through further experimental studies and improved modelling, have been identified.
34
Li, Zihao. "Using data analytics and laboratory experiments to advance the understanding of reservoir rock properties." Thesis, Virginia Tech, 2019. http://hdl.handle.net/10919/87406.
Full textAbstract:
Conventional and unconventional reservoirs are both critical in oilfield developments. After waterflooding treatments over decades, the petrophysical properties of a conventional reservoir may change in many aspects. It is crucial to identify the variations of these petrophysical properties after the long-term waterflooding treatments, both at the pore and core scales. For unconventional reservoirs, the productivity and performance of hydraulic fracturing in shales are challenging because of the complicated petrophysical properties. The confining pressure imposed on a shale formation has a tremendous impact on the permeability of the rock. The correlation between confining pressure and rock permeability is complicated and might be nonlinear. In this thesis, a series of laboratory tests was conducted on core samples extracted from four U.S. shale formations to measure their petrophysical properties. In addition, a special 2D microfluidic equipment that simulates the pore structure of a sandstone formation was developed to investigate the influence of injection flow rate on the development of high-permeability flow channels. Moreover, the multiple linear regression (MLR) model was applied with the predictors based on the development stages to quantify the variations of reservoir petrophysical properties. The MLR model outcome indicated that certain variables were effectively correlated to the permeability. The 2D microfluidic model demonstrated the development of viscous fingering when the injection water flow rate was higher than a certain level, which resulted in reduced overall sweep efficiency. These comprehensive laboratory experiments demonstrate the role of confining pressure, Klinkenberg effect, and bedding plane direction on the gas flow in the nanoscale pore space in shales.Master of Science
Conventional and unconventional hydrocarbon reservoirs are both important in oil-gas development. The waterflooding treatment is the injection of water into a petroleum reservoir to increase reservoir pressure and to displace residual oil, which is a widely used enhanced oil recovery method. However, after waterflooding treatments for several decades, it may bring many changes in the properties of a conventional reservoir. To optimize subsequent oilfield development plans, it is our duty to identify the variations of these properties after the long-term waterflooding treatments, both at the pore and core scales. In unconventional reservoirs, hydraulic fracturing has been widely used to produce hydrocarbon resources from shale or other tight rocks at an economically viable production rate. The operation of hydraulic fracturing in shales is challenging because of the complicated reservoir pressure. The external pressure imposed on a shale formation has a tremendous impact on the permeability of the rock. The correlation between pressure and rock permeability is intricate. In this thesis, a series of laboratory tests was conducted on core samples to measure their properties and the pressure. Moreover, a statistical model was applied to quantify the variations of reservoir properties. The results indicated that certain reservoir properties were effectively correlated to the permeability. These comprehensive investigations demonstrate the role of pressure, special gas flow effect, and rock bedding direction on the gas flow in the extremely small pore in shales.
35
Bon, Nubia J. "Reservoir and production properties of the Toolachee and Patchawarra formations, Cooper Basin, South Australia /." Title page, contents and abstract only, 1999. http://web4.library.adelaide.edu.au/theses/09S.B/09s.bb697.pdf.
Full textAbstract:
Thesis (B.Sc.(Hons.))--University of Adelaide, National Centre for Petroleum Geology and Geophysics, 2000.One col. folded enclosure in pocket inside back cover. Includes bibliographical references (2 leaves).
36
Swierczek, Marta. "Role of unconformities in controlling clastic reservoir properties : insights from adopting a multidisciplinary approach." Thesis, Heriot-Watt University, 2012. http://hdl.handle.net/10399/2551.
Full textAbstract:
It is commonly thought that unconformities may both cause reservoir deterioration by being highly cemented and therefore form low permeability zones, or they promote reservoir development by being associated with coarse-grained sediments that offer high permeability pathways for fluid flow. Unconformity surfaces play a significant role in sequence stratigraphy and correlation of parasequences. However, they are also of fundamental importance for understanding petroleum prospectivity in many sedimentary basins. They commonly promote diagenetic change and either enhance reservoir porosity in subcropping sedimentary layers through leaching or promote cementation to create low permeability, poorer quality reservoirs. This thesis reports the results of a systematic analysis at different scales of the Caledonian and Variscan Unconformities, the two most prominent unconformities affecting British Stratigraphy, to provide new insights for our understanding that the subcrop and supracrop of unconformities are important in controlling reservoir properties. The Base Devonian Unconformity outcropping onshore in the Siccar Point, Scotland, represents the most famous angular unconformity ("Hutton’s Unconformity") and provides an exceptionally well exposed, hitherto unrecognized, wadi channel. Application of a new technique - LiDAR laser scanner, shed new light on this world famous unconformity. By generating a three-dimensional model representing the surface, highly angular character of the unconformity and its controlling factor in the deposition and distribution of the overlying sediments could be reflected. Furthermore, evaluation of the Base Permian Unconformity (BPU) through integration of seismic, electrical well-log, outcrop and core data has afforded the opportunity to determine the effects that it has on highly prospective Carboniferous gas-reservoirs which have been sealed beneath its overlying sealing Lower Permian, Rotliegend Group, Silverpit Claystone Formation cover in the UK Southern North Sea (SNS). Conventional wisdom has polarised views and has been a part of an on-going debate with opinion divided as to whether reservoir properties are enhanced or not by the unconformity. Given the significance for exploration, appraisal and development of the prospective Carboniferous play fairway in the SNS, the research has attempted to resolve this issue through seismic interpretation of the BPU, stratigraphic assessment of supracropping horizons and the systematic sampling and analysis of all relevant field exposures and cored sections. The interpretation of high-fidelity 3D seismic data has also permitted the identification of areas of structural inversion and the presence of a suite of WNW-ESE striking, sub-vertical Tertiary igneous dykes. The zones of structural inversion and the transecting dykes both affect the Carboniferous sediments and the BPU affecting the reservoir quality by instigating additional, overprinting diagenetic changes and the compartmentalisation of the reservoirs.
37
Nourifard, Nazanin. "Effect of Stress Magnitude and Stress Rate on Elastic Properties of the Reservoir Rocks." Thesis, Curtin University, 2019. http://hdl.handle.net/20.500.11937/77386.
Full textAbstract:
We studied the effect of stress magnitude and stress rate on elastic properties of the reservoir rocks. We designed and developed experiments to study: (i) the dynamic and static elastic moduli of reservoir rocks, (ii) quantifying the effects of wave’s amplitude on the longitudinal and transverse velocities in porous media, and (iii) anisotropy of sandstone subjected to stress in dry and saturated statuses.
38
Paipe, Félix António Guimarães. "Masters Thesis Effect of Brine Concentration on Flow Properties in Two Types of Carbonate Rocks Ekofisk Chalk and Iranian Limestone : Study of Chemical Effect of Brine Composition on Flow Properties on Carbonate Rocks." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19269.
Full textAbstract:
SummaryThe displacement of oil from reservoir rock pore spaces is a function of many interacting variables, amongst which the reservoir wetting state has been shown to be one of the important affected by the rock lithology, oil chemistry and brine salinity. A finding from previous research says that the injection brine into oil saturated core plug increased oil recovery. Based on this the objective of this master thesis is to investigate the effect of brine concentration on flow properties in two types of carbonate rocks for enhanced oil recovery (EOR) through imbibition and water flooding processes.The methodology used to evaluate the effect of brine concentration (BC) and chemical composition (CC) for oil recovery consisted on two stages. The first stage covers the literature review regarding the effect of brine concentration and chemical composition, including carbonates (chalk and limestone) characteristics. The second stage is related to the laboratory experiment which was performed using n-Decane oil, six (6) brines with different concentrations and chemical composition and the six (6) core plugs where four (4) “chalks” from Ekofisk (Norway) and the other two (2) “limestones” from Iranian field. The experiment was carried out in the laboratory of Institute of Petroleum and Technology (IPT), the materials, chemicals products, apparatus and equipments, methodology and procedures were provided by the IPT laboratory.To carry out the laboratory experiments, initially the two cores from Iranian were cleaned before being used. Different properties of brines, cores and oil were measured using different methods and procedures; and results were computed. Next, each core was saturated with one type of brine and after that flooded by n-Decane oil for establishment of initial water saturation and determination of volume of oil produced by drainage process at room temperature conditions at one bar. After that, all cores were aging about 15 days at room temperature condition. Finally, each core was flooded using brine by imbibition process at room temperature conditions.Results achieved were computed and discussed based on the literature review and compared with “A salinity (AS) Ekofisk core reference case” and similar studies. From this study was observed that the matrix block has a high porosity. The average porosity was about 40.24% of the volumes of large pores. The average absolute permeability was about 3.73 mD which is low because the microporous dominate the pore network. The average brine density (ρ) was about1.026 g/cm3 and pH was about 7.25. The initial water saturation varies between 14.58 to 28.50% and residual oil saturation among 22.49 to 62%. The sleeve pressure in the cylinder was kept from 15 to 28 bar. During waterfloodig was observed that the breakthrough pressure drop and time to increases when the oil recovery increase.The highest original oil in place (OOIP) was achieved in the low salinity (LS) core which was about 68.46% and the lowest was recorded in the C salinity (CS) core which was around 26.71%. The reason of the high and the low recovery is related with the effect of brine concentration and chemical composition of Sodium, Calcium, Magnesium and Sulphate, added in the solution. The main driving mechanism for low salinity waterflooding is believed to be multi component ionic exchange made possible by the expansion of electrical double layer. The permeability and porosity of the cores can be pointed as other factor. In general, it was showen that there is an increase in oil recovery as the salinity decreases.
39
Cooper, Mark Robert. "Diagenetic evolution and implications for the reservoir properties of selected shallow marine and aeolian sandstones." Thesis, University of Liverpool, 1994. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.260456.
Full textAbstract:
Three sandstones of varying complexity have been examined with the aim of quantifying the effects of compaction and quartz cementation upon their diagenetic evolution. Emphasis has been placed on the scales of heterogeneity, determination of the physical controls on cement distribution, porosity and permeability. The shallow marine, Fontainebleau Sandstone provides a relatively simple system in which to examine progressive porosity and permeability reduction as a result of compaction and quartz cementation. Cement was precipitated as lenses in response to ground water outflow during the recent morphological development of the Paris Basin. Conventional modal and textural analyses using transmitted light proved difficult, because grain/overgrowth boundaries are poorly defined. However, combined SEM BSE CL and image analysis enabled accurate quantification of detrital and authigenic quartz, minus-cement porosity and intergranular porosity. Analyses indicate an extremely mature sand in terms of both mineralogy (100% quartz) and texture (Fine Upper, Well Sorted). Minus-cement porosity values are high (-33%bv) indicating that cementation occurred at a shallow depth. The degree of silicification is the dominant variable control on permeability. Helium porosity and liquid permeability measurements are in the range of 8.6% and 114mO to 26% and 60, the data agree with predicted values. The distribution of quartz cement, in relation to the Eden Valley Basin structure and stratigraphy, for the Penrith Sandstone has been examined via literature review, fieldwork and aerial photographs. Quartz cement is found dominantly north of Cliburn and towards the top of the formation; the base of the formation lacks quartz cement and has undergone greater pressure solution. Models for convective fluid flow are proposed to account for the distribution of cement observed. The Bowscar dune study examines how quartz cement influences dune-scale diagenetic evolution within a transverse aeolian dune. The Locharbriggs dune is used to compare porosity and permeability characteristics. SystematiC sampling of cores cut parallel to lamination and collected horizontally and vertically over the preserved dunes ensured adequate and unbiased sampling. Modal and textural analysis of the Bowscar dune indicate that dune-scale controls on quartz cement distribution include effects of primary depOSitional fabric, detrital mineralogy and compaction. Porosity and permeability measured from the cores give a three-dimensional (3-~) analysis and demonstrates lateral and vertical variations associated with the distribution of lamination types within the dunes. At the lamina scale, 3-D geometrical quantification of detrital framework, quartz cement, minus-cement and intergranular porosity networks has been achieved using preciSion serial grinding/polishing, coupled with SEM BSE CL imaging and 3-~ reconstruction techniques.
40
Owen, Mark Anthony. "The controls on reservoir properties of Devonian sandstones in the Orcadian Basin, north east Scotland." Thesis, University of Reading, 1994. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.239529.
Full text
41
Musu, Junita Trivianty. "Relationship between reservoir properties and NMR measurements : examples from Tirrawarra sandstone, Cooper Basin, South Australia." Title page, abstract and contents only, 2000. http://web4.library.adelaide.edu.au/theses/09SM/09smm991.pdf.
Full text
42
Elashahab, Bashir M. "Effect of wettability, hysteresis and saturation distribution on the electrical properties of rocks at reservoir conditions." Thesis, Imperial College London, 1995. http://hdl.handle.net/10044/1/11222.
Full text
43
Leftwich, R. Wayne. "Reservoir sedimentation and property values a hedonic valuation for waterfront properties along Lake Greenwood, South Carolina /." Connect to this title online, 2007. http://etd.lib.clemson.edu/documents/1181668928/.
Full text
44
Coll, Carolina. "The representation of small scale reservoir properties in the field scale simulation of two-phase flow." Thesis, Imperial College London, 1998. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.269001.
Full text
45
Shabestari, Gholamreza Mirab. "Diagenesis and reservoir properties of the Great Oolite Formation (Middle Jurassic), Weald Basin, south of England." Thesis, University of Liverpool, 2006. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.433035.
Full text
46
Steiner, Katrin [Verfasser]. "The influence of drug core properties on drug release from extended release reservoir pellets / Katrin Steiner." Berlin : Freie Universität Berlin, 2011. http://d-nb.info/1025239733/34.
Full text
47
Grochau, Marcos Hexsel. "Investigation of pressure and saturation effects on elastic parameters: an integrated approach to improve time-lapse interpretation." Thesis, Curtin University, 2009. http://hdl.handle.net/20.500.11937/549.
Full textAbstract:
Time-lapse seismic is a modern technology for monitoring production-induced changes in and around a hydrocarbon reservoir. Time-lapse (4D) seismic may help locate undrained areas, monitor pore fluid changes and identify reservoir compartmentalization. Despite several successful 4D projects, there are still many challenges related to time-lapse technology. Perhaps the most important are to perform quantitative time-lapse and to model and interpret time-lapse effects in thin layers. The former requires one to quantify saturation and pressure effects on rock elastic parameters. The latter requires an understanding of the combined response of time-lapse effects in thin layers and overcoming seismic vertical resolution limitation.This thesis presents an integrated study of saturation and pressure effects on elastic properties. Despite the fact that Gassmann fluid substitution is standard practice to predict time-lapse saturation effects, its validity in the field environment rests upon a number of assumptions. The validity of Gassmann equations, ultimately, can only be tested in real geological environments. In this thesis I developed a workflow to test Gassmann fluid substitution by comparing saturated P-wave moduli computed from dry core measurements with those obtained from sonic and density logs. The workflow has been tested on a turbidite reservoir from the Campos Basin, offshore Brazil. The results show good statistical agreement between the P-wave elastic moduli computed from cores using the Gassmann equations and the corresponding moduli computed from log data. This confirms that all the assumptions of the Gassmann theory are adequate within the measurement error and natural variability of elastic properties. These results provide further justification for using the Gassmann theory to interpret time-lapse effects in this sandstone reservoir and in similar geological formations.Pressure effects on elastic properties are usually obtained by laboratory measurements, which can be affected by core damage. I investigated the magnitude of this effect on compressional-wave velocities by comparing laboratory experiments and log measurements. I used Gassmann fluid substitution to obtain low-frequency saturated velocities from dry core measurements taken at reservoir pressure, thus mitigating the dispersion effects. The analysis is performed for an unusual densely cored well from which 43 cores were extracted over a 45 m thick turbidite reservoir. These computed velocities show very good agreement with the sonic-log measurements. This is encouraging because it implies that core damages that may occur while bringing the core samples to the surface are small and do not adversely affect the measurement of elastic properties on these core samples. Should core damage have affected our measurements, we would have expected a systematic difference between properties measured in situ and on the recovered. This confirms that, for this particular region, the effect of core damage on ultrasonic measurements is less than the measurement error. Consequently, stress sensitivity of elastic properties as obtained from ultrasonic measurements are adequate for quantitative interpretation of time-lapse seismic data.In some circumstances, stress sensitivity may not be obtained by ultrasonic measurements. Cores may be affected by damage, bias in the plugging process and scale effects and therefore may not be representative of the in situ properties. Consequently it is desirable to obtain this dependence from an alternative method. This other approach ideally should provide the pressure - velocity dependence from an intact rock. Few methods can sample the in situ rock. Seismic, for instance, provides in situ information, but lacks vertical resolution. Well logs, on the other hand, can provide high vertical resolution information, but usually are not available before and after production changes. I propose a method to assess the in situ pressure - velocity dependence using well data. I apply this method to a reservoir made up of sandstone. I used 23 wells drilled and logged in different stages of development of a hydrocarbon field providing rock and fluid properties at different pressures. For each well logged at a specific time, pore pressure, velocity and porosity, among other properties, are known. Pore pressure is accessed from a Repeat Formation Tester (RFT). As a field depletes and new wells are drilled and logged, similar data sets related to different stages of depletion are available. I present an approach expanding Furre et al. (2009) study incorporating porosity and obtaining a three dimensional relationship with velocity and pressure. The idea is to help to capture rock property variability.Quantitative time-lapse studies require precise knowledge of the response of rocks sampled by a seismic wave. Small-scale vertical changes in rock properties, such as those resulting from centimetre scale depositional layering, are usually undetectable in both seismic and standard borehole logs (Murphy et al., 1984). I present a methodology to assess rock properties by using X-ray computed tomography (CT) images along with laboratory velocity measurements and borehole logs. This methodology is applied to rocks extracted from around 2.8 km depth from offshore Brazil. This improved understanding of physical property variations may help to correlate stratigraphy between wells and to calibrate pressure effects on velocities, for seismic time-lapse studies.Small scale intra-reservoir shales have a very different response from sands to fluid injection and depletion, and thus may have a strong effect on the equivalent properties of a heterogeneous sandstone reservoir. Since shales have very low permeability, an increase of pore pressure in the sand will cause an increase of confining pressure in the intra-reservoir shale. I present a methodology to compute the combined seismic response for depletion and injection scenarios as a function of net to gross (NTG or sand – shale fraction). This approach is appropriate for modelling time-lapse effects of thin layers of sandstones and shales in repeated seismic surveys when there is no time for pressure in shale and sand to equilibrate. I apply the developed methodology to analyse the sand - shale combined response to typical shale and sandstone stress sensitivities for an oil field located in Campos Basin, Brazil. For a typical NTG of 0.6, there is a difference of approximately 35% in reflection coefficient during reservoir depletion from the expected value if these shales are neglected. Consequently, not considering the small shales intra-reservoir may mislead quantitative 4D studies.The results obtained in this research are aimed to quantify pressure and saturation effects on elastic properties. New methodologies and workflows have been proposed and tested using real data from South America (Campos Basin) datasets. The results of this study are expected to guide future time-lapse studies in this region. Further investigations using the proposed methodologies are necessary to verify their applicability in other regions.
48
Sánchez, Sánchez-Pastor Pilar. "Monitoring the subsurface elastic properties using ambient seismic noise: 2011 El Hierro eruption and Reykjanes geothermal reservoir." Doctoral thesis, Universitat de Barcelona, 2019. http://hdl.handle.net/10803/668464.
Full textAbstract:
Monitoring the elastic properties of the subsurface is of a special interest to mitigate the associated risk with natural and artificial hazards. In the last decade, coda-wave interferometry has become an excellent tool to characterize the subsurface in a large variety of environments. Additionally, coda-wave interferometry applied to the ever-present seismic ambient noise enables a continuous retrieval of virtual-source responses that allows monitoring structural and mechanical changes of media.
Throughout this thesis, we perform a comprehensive study of seismic noise interferometry employing all the currently used methodologies to observe lag-time changes: Time evolution of waveform similarity, waveform stretching and moving window cross-spectrum technique. Furthermore, we introduce some improvements in order to increase the temporal accuracy and sensitivity of said methodologies to detect tiny medium changes.
In particular, we carry out the study in two scenarios with very di fferent tectonic settings: the 2011 El Hierro eruption and the Reykjanes geothermal system (RGS). We compute the phase auto- and cross-correlation (PCC) of 1.5 years of continuous seismic noise records of all available seismic stations in both cases. The PCC provides an accurate and amplitude-unbiased measure of coherence between two seismic traces and allows obtaining detailed daily seismic response of media.
In the case of the 2011 El Hierro volcanic eruption, through the analysis of waveform similarity time series of auto-correlations we clearly identify different pre-eruptive phases, as well as the end of the main magmatic emission and three magmatic intrusions that occurred in 2012. We use probabilistic sensitivity kernels to locate the places of the highest dynamics, providing that the ected areas correspond to the magmatic accumulation zone and the extinct volcanic area of Tiñor. In this study, we also introduce the change point analysis approach in order to automatically detect significant changes in time series.
The second scenario consists in studying stress changes and potential deformations of the subsurface caused by geothermal well operations at RGS. For that purpose, we retrieve and analyse time series of waveform similarity values and seismic velocity variations. However, the continuous production over a large area and various injection wells make challenging the detection of time-lag changes in the coda. To tackle this issue, we decompose the similarity time series into the time-frequency domain through the S- transform, which allows us to discriminate fluctuations associated to injection and production rate drops. Furthermore, we observe a slow seismic velocity decrease in the reservoir due to the water deficit as well as seasonal variations associated with the energy production demand.El monitoreo de las propiedades elásticas del subsuelo es de especial interés para mitigar el riesgo asociado con peligros naturales y artificiales. En la última década, la interferometría de ondas de coda (coda-wave interferometry) se ha convertido en una excelente herramienta para caracterizar el subsuelo en una gran variedad de escenarios. Además, esa metodología aplicada al ruido sísmico ambiental, el cual está siempre presente en los registros sísmicos, permite calcular de forma continua las respuestas sísmicas del medio (o funciones de Green) y así monitorear los cambios estructurales y mecánicos de los medios. En esta tesis, hemos realizado un estudio exhaustivo de la interferometría de ruido sísmico empleando todas las metodologías utilizadas actualmente para observar cambios temporales: similitud de la forma de onda, estiramiento de la forma de onda (stretching) y la técnica de moving window cross-spectrum. Además, introducimos algunas mejoras para aumentar la precisión temporal y la sensibilidad de dichas metodologías para detectar pequeños cambios en el medio. En particular, hemos llevado a cabo el estudio en dos escenarios con marcos tectónicos muy diferentes: la erupción de El Hierro de 2011 y el sistema geotérmico de Reykjanes (RGS). Calculamos auto-correlaciones y correlaciones cruzadas de fase (phase cross-correlation) de 1,5 años de registros continuos de ruido sísmico de todas las estaciones sísmicas disponibles en ambos casos. La PCC proporciona una medida precisa de la coherencia entre dos trazas sísmicas la cual no está condicionada por la amplitud de dichas trazas. De esta forma, hemos obtenido una detallada y diaria respuesta sísmica del medio. En el caso de la erupción volcánica de El Hierro de 2011, a través del análisis de la evolución temporal de las similitudes de forma de onda de auto-correlaciones, identificamos las diferentes fases pre-eruptivas de la erupción, así como el final de la emisión magmática y las tres intrusiones magmáticas ocurridas en 2012. Utilizamos sensitivity kernels para localizar los lugares de mayor dinamismo durante la crisis volcánica. Resultando que las áreas más afectadas son la zona de acumulación magmática alrededor del volcán Tanganasoga y al área volcánica extinta de Tiñor. En este estudio, presentamos el change-point analysis para detectar automáticamente cambios significativos en las series de tiempo y así poder automatizar su búsqueda con un bajo coste computacional. La segunda parte de la tesis consiste en estudiar cambios de esfuerzos y posibles deformaciones del subsuelo causadas por las operaciones de los pozos geotérmicos en RGS. Con este fin, calculamos y analizamos las series temporales de los valores de similitud de forma de onda y variaciones de velocidad sísmica. Sin embargo, la producción de energía se produce de forma continua y hay varios pozos de inyección de fluidos distribuidos por la zona de estudio, esta perturbación continuada del medio dificulta la detección de cambios temporales en la coda. Por ello, abordamos el estudio descomponiendo las series de tiempo de similitud en el dominio de tiempo-frecuencia a través de la transformada S. Esto nos permite discriminar las fluctuaciones en la coda que están asociadas a las variaciones bruscas que se producen en la actividad de la planta geotérmica. Por otro lado, observamos una disminución lenta de la velocidad sísmica en el reservorio debido al déficit de agua que está causando el sistema geotérmico. Por último, observamos variaciones estacionales en el subsuelo que acompañan a la demanda de producción de energía de la población islandesa.
49
Sinka, Iosaf Csaba. "An investigation into rock and reservoir properties of coal with special reference to simulated coalbed methane performance." Thesis, Imperial College London, 1998. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.299244.
Full text
50
Aubert, Irène. "Fault zone structural and diagenetic evolution in carbonates : impact on reservoir properties (urgonian case study, SE France)." Thesis, Aix-Marseille, 2020. http://www.theses.fr/2020AIXM0175.
Full textAbstract:
Les zones de failles ont un impact important sur les réservoirs carbonatés car elles peuvent agir comme des drains ou des barrières en fonction de leurs propriétés structurales et diagénétiques. Il est important de bien comprendre ces propriétés pour déterminer les caractéristiques hydrauliques des zones de failles. Pour cela, l'approche multidisciplinaire de cette thèse combinant l’analyse structurale, diagénétique et géochimique vise à (1) contraindre l'évolution structurale et diagénétique des zones de failles dans les carbonates, (2) établir des règles et des concepts géométriques permettant de construire des modèles géologiques cohérents, et (3) permettre une meilleure compréhension de la réponse dynamique hydraulique des zones de failles dans les carbonates à travers leurs évolutions. Nous avons étudié 3 zones de failles (Castellas, D19) affectant les carbonates de plate-forme du Barrémien inférieur (faciès Urgonien) situées dans l'anticlinal de La Fare et dans celui de la Nerthe (Provence - SE France). Ces travaux ont permis de restaurer les séquences diagénétiques des zones de failles avec des analyses de ciment sous catholuminescence et des mesures des isotopes 13C et 18O. L'analyse structurale a permis de compléter l'évolution diagénétique en déterminant les caractéristiques architecturales liées à chaque activité de faille et en discriminant l'effet des structures préexistantes sur le développement ultérieur de ces dernières. Enfin, cette étude a permis d'améliorer notre compréhension du comportement hydraulique des zones de failles dans les carbonates au cours tempsFault zones strongly impact carbonates reservoir properties as they can act as drains or barriers depending of their structural and diagenetic properties. Hence, it is important to have an integrativecomprehension of these properties that affect the fault zones hydraulic properties. To this end, the multidisciplinary approach of this thesis combining structural, diagenetic and geochemical approaches aims to (1) constrain the structural and diagenetic evolution of fault zones in carbonates (2) draw rules and geometrical concepts allowing building of coherent geological models, and (3) allow a better understanding of the hydraulic dynamic response of fault zones in carbonates through their evolutions. We studied 3 fault zones (Castellas, D19) affecting lower Barremian platform carbonates (Urgonian facies) located in La Fare and Nerthe anticlines (Provence – SE France). This work allowed the restoration of fault zones diagenetic sequences with cement analyses under catholuminescence and 13C and 18O isotopes. The structural analysis completed the diagenetic evolution by determining the architectural characteristics related to each fault activity and discriminating the effect of pre-existing structures on subsequent fault development. Finally, this study improved our understanding of fault zones hydraulic behaviour in carbonates through times