Dissertations / Theses on the topic 'Hydrocarbon basins'
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Monson, Bryan J. G. "Aspects of hydrocarbon migration and hydrocarbon-metal interactions in sedimentary basins." Thesis, Queen's University Belfast, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.333838.
Full textWang, Weihua. "Studies of sandstone diagenesis in hydrocarbon-prospective basins." Thesis, Queen's University Belfast, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.333852.
Full textMohammed, Wolela Ahmed. "Sedimentology, diagenesis and hydrocarbon potential of sandstones in hydrocarbon prospective Mesozoic rift basins (Ethiopia, UK and USA)." Thesis, Queen's University Belfast, 1997. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.394602.
Full textWard, Nicholas I. P. "Subtle traps in sedimentary basins and their importance to hydrocarbon exploration." Thesis, Cardiff University, 2018. http://orca.cf.ac.uk/113131/.
Full textReynolds, Peter William. "Monogenetic basaltic edifices : their architecture, volcanology and importance in hydrocarbon basins." Thesis, Durham University, 2015. http://etheses.dur.ac.uk/11369/.
Full textSpry, Trent B. "Source potential index (SPI) as a hydrocarbon prospectivity ranking factor in Australian Basins /." Title page, contents and abstract only, 1993. http://web4.library.adelaide.edu.au/theses/09SB/09sbs771.pdf.
Full textVolume 2 is loose leaf and contains all the Appendices. Includes bibliographical references.
Muia, George. "The ''Turkana Grits'' : Potential Hydrocarbon Reservoirs of the Northern and Central Kenya Basins." Thesis, Rennes 1, 2015. http://www.theses.fr/2015REN1S069/document.
Full textOver two thirds of the world’s giant oilfields are found in two principle tectonic regimes; continental passive margins and continental rifts. The preferential formation of hydrocarbons in rifts is attributed to the proximal juxtaposition of high grade, lacustrine source rock units with medium to high grade reservoir rocks - a consequence of both faulting and sedimentation in the resulting accommodation space, which in many cases may locally modify the prevailing climatic conditions. In one of such basins, the Lokichar Basin in the Kenyan Rift, over 600 million barrels of recoverable oil have been discovered. The principle reservoir unit in this basin is the Lokone Sandstone that belongs to a larger family of sandstones called the ‘Turkana Grits’, arkosic sandstones that are sandwiched between metamorphic basement and mid-Miocene volcanics. The hydrocarbon proclivity of the Lokone Sandstones as reservoir units motivated further study of the ‘Turkana Grits’, as potential hydrocarbon reservoirs. In this work, three sedimentary formations, i.e. Kimwarer Formation, Kamego Formation and Loriu Sandstones, which have not been previously fully characterized from chronostratigraphic and sedimentological point of views were studied through detailed logging. Over 170 samples were collected to determine, detrital and authigenic components, the main cementation zones in the different outcrops, and, from lithofacies analysis, the depositional environments. Volcanic and intrusive samples were also characterized and used for 39Ar-40Ar dating. Three superposed depositional environments were determined for the Kimwarer Formation, a distal fluvial channel, an alluvial fan and a floodplain depositional environment. The diagenetic study shows cements change from dominant hematite at the base to calcite within the middle zones and back to hematite towards the top of the Formation. These cementation episodes occur during early and relatively late diagenesis in low temperature conditions (<80 °C), under significant mechanical compaction. A minimum deposition age at ca. 18 Ma (Early Miocene – Burdigalian) has also been set for the Kimwarer Formation. The Kamego Formation evolves from fluvial to floodplain depositional environments and is dominantly cemented by hematite. Calcite cement is only noted in the lowermost 5m. A thin lava flow interbedded with the topmost sediments of the Kamego Formation gave a minimum deposition age of ca. 20 Ma for most of the sediments. The Loriu Sandstone is composed predominantly of fluvial channel deposits. The main cements are calcite, hematite and kaolinite clays. A cross-cutting dyke suggests a minimum deposition age of ca. 18.5Ma. A final reservoir analysis of the Turkana Grits shows that while compaction and cementation are dominant agents of porosity reduction, the Turkana Grits are generally poor to moderately good reservoir units. The Lokone Sanstone has been proven to have sub-surface porosities ranging between 10 - 20% and permeabilities as high as 3 darcies (Africa Oil Corporation, 2011). For petrographic analyses, the Kimwarer Formation has been ranked as having the second best reservoir potential with porosities as high as 20% in some sections of its studied stratigraphy. The Kamego Formation also has good potential but is not as highly ranked owing to the huge component of volcanic material that have a greater propensity to diagenetic alteration. No good porosities were noted for the Loriu Sandstone and hence this formation has been ranked 5th amongst the Turkana Grits
Kloss, Olaf. "The relationship of faulting to hydrocarbon accumulations in the Barrow and Exmouth Sub-basins /." Title page, abstract and table of contents only, 1996. http://web4.library.adelaide.edu.au/theses/09S.B/09s.bk66.pdf.
Full textGillam, Daniel J. "Structural and geomechanical analysis of naturally fractured hydrocarbon provinces of the Bowen and Amadeus Basins: onshore Australia /." Title page, table of contents and abstract only, 2004. http://web4.library.adelaide.edu.au/theses/09PH/09phg4758.pdf.
Full textSpaak, Gemma. "Molecular and isotopic perspectives on Australian petroleum systems: Hydrocarbon fluid correlations and source rock depositional environments in the Canning and Browse basins." Thesis, Curtin University, 2017. http://hdl.handle.net/20.500.11937/69412.
Full textMohamed, Abdalla Yagoub. "Basin analysis and hydrocarbon maturation, Unity and Kaikang area, Muglad Basin, Sudan." Thesis, University of Aberdeen, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.390934.
Full textAlalade, Babatunde. "Hydrocarbon Potential of Late Cretaceous Shales, Chad Basin, NE Nigeria." Thesis, University of Newcastle Upon Tyne, 2006. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.519492.
Full textZhakiya, Elezhan. "Using machine learning for hydrocarbon prospecting in Reconcavo Basin, Brazil." Thesis, Massachusetts Institute of Technology, 2016. http://hdl.handle.net/1721.1/115039.
Full textCataloged from PDF version of thesis.
Includes bibliographical references (pages [28]).
Machine Learning techniques are being widely used in Social Sciences to find connections amongst various variables. Machine Learning connects features across different fields that do not seem to have known mathematical relationships with each other. In natural resource prospecting, machine learning can be applied to connect geochemical, geophysical, and geological variables. However, the biggest challenge in machine learning remains obtaining the data to train the ML algorithms. Here, we have applied machine learning on data extracted from maps via image processing. While the overall accuracy of prediction remains as low as 33% at this stage, we see places where the algorithm can be improved and the accuracy increased.
by Elezhan Zhakiya
S.B.
Pei, Yangwen. "Thrust fault evolution and hydrocarbon sealing behaviour, Qaidam Basin, China." Thesis, University of Leeds, 2013. http://etheses.whiterose.ac.uk/5831/.
Full textBoe, Jennifer Barber. "Removal of hydrocarbons from urban stormwater runoff by gravity separation." Thesis, This resource online, 1993. http://scholar.lib.vt.edu/theses/available/etd-10312009-020227/.
Full textRamphaka, Lerato Priscilla. "Integrating 3D basin modelling concept to determine source rock maturation in the F-O Gas Field, Bredasdorp Basin (offshore South Africa)." Thesis, University of the Western Cape, 2015. http://hdl.handle.net/11394/5340.
Full textThe burial history, thermal maturity and petroleum generation history of the F-O Gas Field, Bredasdorp Basin have been studied using 3D basin and petroleum systems modelling approach. The investigated sedimentary basin for this study evolved around mid-late Jurassic to early Cretaceous times when Southern Africa rifted from South America. The F-O field is located 40 km SE of the F-A platform which supplies gas and condensate to the PetroSA ‘Gas to Liquid’ plant located in Mossel Bay. As data integration is an integral part of the applied modelling concept, 2D seismic profile and well data (i.e. logs and reports from four drilled wells) were integrated into a 3D structural model of the basin. Four source rock intervals (three from the Early Cretaceous stages namely; Hauterivian, Barremian, Aptian and one from the Late Cretaceous Turonian stage) were incorporated into the 3D model for evaluating source rock maturation and petroleum generation potential of the F-O Gas Field. Additionally, measured present-day temperature, vitrinite reflectance, source potential data, basin burial and thermal history and timing of source rock maturation, petroleum generation and expulsion were forwardly simulated using a 3D basin modelling technique. At present-day, Turonian source rock is mainly in early oil (0.55-0.7% VRo) window, while the Aptian and Barremian source rocks are in the main oil (0.7-1.0% VRo) window, and the Hauterivian source rock is mainly in the main oil (0.7-1.0% VRo) to late oil (1.0-1.3% VRo) window. In the entire four source rock intervals the northern domain of the modelled area show low transformation, indicated by low maturity values that are attributable to less overburden thickness. Petroleum generation begins in later part of Early Cretaceous, corresponding to high heat flow and rapid subsidence/ sedimentation rates. The Barremian and Aptian source rocks are the main petroleum generators, and both shows very high expulsion efficiencies. The modelling results however indicate that the younger Aptian source rock could be regarded as the best source rock out of the four modelled source rocks in the F-O field due to its quantity (i.e. highest TOC of 3%), quality (Type II with HI values of 400) and highest remaining potential. At present-day, ~1209 Mtons of hydrocarbons were cumulatively generated and peak generation occurred at ~43 Ma with over 581 Mtons generated. Finally, the results of this study can directly be applied for play to prospect risk analysis of the F-O gas field.
Razafimbelo, Eugène. "Le bassin de morondava (madagascar) : synthese geologique et structurale." Université Louis Pasteur (Strasbourg) (1971-2008), 1987. http://www.theses.fr/1987STR13184.
Full textLisk, Mark. "Fluid migration and hydrocarbon charge history of the vulcan sub-basin." Thesis, Curtin University, 2012. http://hdl.handle.net/20.500.11937/1932.
Full textDiyarbakirli, Ali Can. "Stratigraphic Analysis and Reservoir Characterization of the Late Oligocene-Early Miocene, Upper Yenimuhacir Group, Thrace Basin, Turkey." Thesis, Virginia Tech, 2016. http://hdl.handle.net/10919/73651.
Full textMaster of Science
Quaglia, Laurent. "Contribution à l'étude des écoulements diphasiques avec capillarité." Thesis, Aix-Marseille, 2017. http://www.theses.fr/2017AIXM0567.
Full textNumerical modeling of hydrocarbon migration in sedimentary basins makes it possible to determine hydrocarbon accumulations within geological formations. From this it is possible to predict the trapped hydrocarbon height. This determination is essential in the petroleum industry. However, thanks to some studies, it has been found that numerical errors can occur when using polynomial capillary pressure. In this thesis, we work mainly on the so-called models of Darcy and we briefly discuss percolation-type models. The objective of this work is to provide new models of capillary pressures, giving better results than those currently used. First, we describe the mechanisms of hydrocarbon migration in the layers. Then we study more closely the laws of capillary pressures allowing the flow of fluids. Then we establish the discretization, according to the finite volume method, of the problem. In the next part we test in one dimension new models of capillary pressures affine in pieces. Then in another part, we do the two-dimensional tests of these models to which we add another model, built from the two previous ones. In conclusion, we summarize all the results and discuss some perspectives concerning the improvement of the studied models
Clarke, Stuart. "Faulting, fault zone processes and hydrocarbon flow through three-dimensional basin models." Thesis, Keele University, 2001. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.394652.
Full textMachado, Vladimir Alberto Gouveia. "Sand provenance, diagenesis and hydrocarbon charge history of the Kwanza Basin, Angola." Thesis, University of Aberdeen, 2007. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=225701.
Full textBird, Peter Cameron. "Tectono-stratigraphic evolution of the West Orkney Basin : implications for hydrocarbon exploration." Thesis, Cardiff University, 2014. http://orca.cf.ac.uk/73653/.
Full textMagoba, Moses. "Petrophysical evaluation of sandstone reservoir of well E-AH1, E-BW1 and E-L1 Central Bredasdorp Basin, offshore South Africa." University of the Western Cape, 2014. http://hdl.handle.net/11394/4462.
Full textThe Bredasdorp basin is a sub-basin of the greater Outeniqua basin. It is located off the south coast, Southeast of Cape Town, South Africa. This basin is one of the largest hydrocarbon (mainly gas) producing basins within Southern Africa. The petrophysical characteristic of the E-block sandstone units within the Bredasdorp basin has been studied to evaluate their hydrocarbon potential. The data sets used in this research were wireline logs (Las format), core data, and geological well completion reports. The three studied wells are E-AH1, E- BW1 and E-L1. The evaluated interval ranges from 2000.33m to 3303.96m in depth with reference to Kelly bushing within the wells. The sandstone reservoirs of the Bredarsdorp basin are characterized by a range of stacked and amalgamated channels. They originated from materials eroded from pre-existing high stand shelf sandstone and transported into the central Bredarsdorp basin by turbidity current. These sandstones are generally in both synrift and drift section. The basin is thought to have developed from fan deltas and stream overwhelmed to water dominated delta. River dominated deltaic system progresses southward over the Northern edge of the central Bredasdorp basin. The Interactive Petrophysics (IP) software has been used extensively throughout the evaluation and development of interpretation model. The lithofacies of the rock units were grouped according to textural and structural features and grain sizes of well (E-AH1, E-BW1 and E-L1). Four different facies (A, B, C and D) were identified from the cored intervals of each well. Facies A was classified as a reservoir and facies B, C and D as a non-reservoir. Detailed petrophysical analyses were carried out on the selected sandstone interval of the studied wells. The cut-off parameters were applied on the seven studied sandstone interval to distinguish between pay and non-pay sand and all intervals were proved to be producing hydrocarbon. Volume of clay, porosity, water saturation and permeability were calculated within the pay sand interval. The average volume of clay ranged from 23.4% to 25.4%. The estimated average effective porosity ranged from 9.47% to 14.3%. The average water saturation ranged from 44.4% to 55.6%. Permeability ranged from 0.14mD to 79mD. The storage and flow capacity ranged from 183.2scf to 3852scf and 2.758mD-ft to 3081mD-ft respectively. The geological well completion reports classify these wells as a gas producing wells. E-L1 is estimated to have a potential recoverable gas volume of 549.06 cubic feet, E-BW1 is estimated to have 912.49 cubic feet and E-AH1 is estimated to have 279.69 cubic feet.
Acho, Collins Banajem. "Assessing hydrocarbon potential in cretaceous sediments in the Western Bredasdorp Sub-basin in the Outeniqua Basin South Africa." University of the Western Cape, 2015. http://hdl.handle.net/11394/4807.
Full textThe Bredasdorp Basin is one of the largest hydrocarbon producing blocks within Southern Africa. The E-M field is situated approximate 50 km west from the FA platform and was brought into commission due to the potential hydrocarbons it may hold. If this field is brought up to full producing capability it will extend the lifespan of the refining station in Mosselbay, situated on the south coast of South Africa, by approximately 8-10 years. This study is focused in block 9 off shore western part of the Bredasdorp Basin in the main Outeniqua Basin South Africa. Cretaceous Sandstone reservoirs are commonly heterogeneous consequently they may require special methods and techniques for description and evaluation. Reservoir characterization is the study of the reservoir rocks, their petrophysical properties, the fluids they contain or the manner in which they influence the movement of fluids in the subsurface. The main goal of the research is to assess the potentials of hydrocarbons in Cretaceous sediments in the Bredasdorp Basin through the integration and comparison of results from core analysis, production data and petrography studies for the evaluation and correction of key petrophysical parameters from wireline logs which could be used to generate an effective reservoir model for wells (E-BB1, E-BD2, EA01) in the Bredasdorp Basin. Porosity and permeability relationships, wire-line log data have been examined and analysed to determine how the porosity and permeability influence reservoir quality which further influences the potential of hydrocarbon accumulation in the reservoirs. The reservoir sandstone is composed mainly of fine to medium grained Sandstones with intercalation of finger stringers of Siltstone and Shale. In carrying out this research the samples are used to characterize reservoir zones through core observation, description and analyses and compare the findings with electronic data obtained from Petroleum Agency of South Africa (PASA). Secondary data obtained from (PASA) was analysed using softwares such as Interactive Petrophysics (IP), Ms Word, Ms excel and Surfer. Wireline logs of selected wells (E-BB1, E-BD2, E-A01) were generated, analysed and correlated. Surfer software also used to digitize maps of project area, porosity and permeability plotted using IP. Formation of the Bredasdorp Basin and it surrounding basins during the Gondwana breakup. The Bredasdorp Basin consists mainly of tilting half graben structures that formed through rifting with the break-up of Gondwanaland. The model also revealed that these faults segregate the reservoir which explains the pressure loss within the block. The production well was drilled, confining pressure relieved and pressure dropped hence production decreases. The age, transportation, deposition and thermal history of sediment in the basin, all plays a vital role in the type of hydrocarbon formation. Structural features such as faults, pore spaces determines the presence of a hydrocarbon in the reservoir. Traps could be stratigraphic or structural which helps prevent the migration of hydrocarbons from the source rock to reservoir rock or from reservoir rock to the surface over a period of time. The textural aspects included the identification of grain sizes, sorting and grain shapes. The diagenetic history, constructed from the results of the reservoir quality study revealed that there were several stages involved in the diagenetic process. It illustrated several phases of cementation with quartz, carbonate and dolomite with dissolution of feldspar. A potentially good reservoir interval was identified from the data and was characterized by several heterogeneous zones. Identifying reservoir zones was highly beneficial during devising recovery techniques for production of hydrocarbons. Secondary recovery methods have thus been devised to enhance well performance. As recommendation, additional wells are required to appraise the E-M structure and determine to what extent the cement present in the basin has affected fluid flow as well as the degree of sedimentation that could impede fluid flow. There are areas still containing untapped resources thus the recommendation for extra wells. This research may well be reviewed with more data input from PetroSA (wells, seismic and production data) for additional studies, predominantly with respect to reservoir modelling and flow simulation. Based on the findings of this research, summary of calculated Net Pay shows that in well E-BB1, reservoir (1) is at depth 2841.5m – 2874.9m has a Gross Thickness of 33.40m, Net Pay of 29.72 and Pay Summary of 29.57 and reservoir (2) has depth of 2888.1m – 2910.5m, Gross Thickness of 22.40m, Net Pay of 19.92m and Pay summary of 1.48m. Well E-AO1 has depth from 2669.5m – 2684.5m and Gross Thickness of 15.00m and has Net Pay of 10.37m and Pay Summary of 10.37m. Based on the values obtained from the data analysed the above two wells displays high potential of hydrocarbon present in the reservoirs. Meanwhile well E-BD2 has depth from 2576.2m – 2602.5m and has Gross Thickness of 350.00m, Net Pay of 28.96m and Pay Summary of 4.57 hence from data analysis this reservoir displays poor values which is an indication of poor hydrocarbon potentials.
Huyen, Bui Thi Thanh. "Basin development and hydrocarbon potential of the Song Hong basin, Vietnam, insights from numerical simulation and seismic interpretation." 京都大学 (Kyoto University), 2006. http://hdl.handle.net/2433/143965.
Full text0048
新制・課程博士
博士(工学)
甲第12266号
工博第2595号
新制||工||1366(附属図書館)
24102
UT51-2006-J259
京都大学大学院工学研究科社会基盤工学専攻
(主査)教授 松岡 俊文, 教授 芦田 讓, 教授 朝倉 俊弘
学位規則第4条第1項該当
Ma, KeYang. "Hydrocarbon source and depositional environments in the central Papual Basin, Papua New Guinea /." [St. Lucia, Qld.], 2005. http://www.library.uq.edu.au/pdfserve.php?image=thesisabs/absthe18901.pdf.
Full textDavies, Christopher Paul Norman, A. Rozendaal, and B. V. Burger. "Hydrocarbon evolution of the Bredasdorp Basin, offshore South Africa : from source to reservoir." Thesis, Stellenbosch : University of Stellenbosch, 1997. http://hdl.handle.net/10019.1/4936.
Full text1123 leaves printed on single pages, preliminary pages and numbered pages 1-286. Includes bibliography, list of figures and tables and explanation of abbreviations used.
Digitized at 600 dpi grayscale to pdf format (OCR), using a Bizhub 250 Konica Minolta Scanner.
ENGLISH ABSTRACT: This first comprehensive study of the petroleum geochemistry of the Bredasdorp Basin, and the adjacent Southern Outeniqua Basin, documents the characteristic large number of hydrocarbon shows and the four regionally distinctive marine source rocks. Detailed correlation of reservoired hydrocarbons with source rock bitumens shows that two source rocks have expelled oil in commercial quantities and two others have expelled commercial quantities of wet gas/condensate. In contrast with earlier studies which indicated that thermal 'gradualism' prevailed, this study indicates that the post-rift thermal history of the basin is very complex. Post-rift cool-down is punctuated by periods of rapidly increasing heat flow resulting in much of the maturation being localised in time. These periods of increased heating coincide with regional plate tectonism. The associated thermal uplift and downwarp effects govern the periods of trap formation and control the hydrocarbon migration direction. Migration distances of these hydrocarbons are described and show inter alia that oil migrates no more than -7-10 km but gas migrates regionally. Two regional episodes of meteoric water flushing reduce sandstone cementation in palaeo-highs forming potential reservoirs at specific times. The unusually low salinity of remnants of this water in some sandstones help characterise these two main migration conduits. A highly detailed hydrocarbon correlation scheme derived from gas, light oil and biomarker data has been established which differentiates products of the four active source rocks and helps characterise the oil-oil, oil-source and source-source pairs. It is evident from these correlations that two periods of migration and reservoiring occurred at 50-60 Ma and 0-10 Ma. As a result, source-reservoir plays which characterise certain areas of the basin as predominantly oil or gas prone can be described. These correlations also highlight areas where mixtures of hydrocarbons are common and where some of the early reservoired oil has been displaced to new locations, constituting potential new exploration plays. Source rocks for some of the analysed hydrocarbons have yet to be found and may not even have been drilled to date. One such source rock appears to be located in the Southern Outeniqua Basin, making that area a potential target for further exploration. This study resolved the common heritage of the source rocks and reservoir sandstones which form part of the Outeniqua petroleum system. The hydrocarbon volumes available to this system show that by world standards it is indeed significant.
AFRIKAANSE OPSOMMING: Die groot aantal koolwaterstof voorkomste asook vier streekskenmerkende mariene brongesteentes word in hierdie eerste omvattende studie van die petroleumgeochemie van die Bredasdorp-kom en die aangrensende Suidelike Outeniqua-kom saamgevat. Gedetaileerde korrelasies van die opgegaarde koolwaterstowwe met brongesteente bitumen, dui daarop dat twee van die vier geidentifiseerde brongesteentes olie in kommersiele hoeveelhede uitgeset het. Die ander twee het kommersiele hoeveelhede nat gas-kondensaat uitgeset. In teenstelling met vroeer studies wat daarop gedui het dat termale 'gradualisme' voorgekom het, dui hierdie studie daarop dat die na-riftermale geskiedenis van die kom baie meer kompleks is. Verskeie periodes van versnelde toename in hittevloei het voorgekom in die na-rifse verkoeling. Dit het daartoe gelei dat veroudering plaaslik binne 'n beperkte tydsverloop plaasvind. Hierdie periodes van hittetoename stem ooreen met die regionale plaattektoniek. Die geassosieerde termiese opheffing en afwaartse vervormingseffek, beheer die totstandkoming van opvanggebiede en die migrasierigting van die koolwaterstowwe. Migrasie-afstande van die koolwaterstowwe word bespreek en wys inter alia daarop dat olie nie verder as -7-10 km beweeg nie, maar gasmigrasie vind regionaal plaas. Twee kort episodes van meteoriese wateruitsetting, het sandsteensementasie in palaeohoogsliggende gebiede verminder wat potensiele reservoirs gevorm het op spesifieke tye. Die ongewone lae soutvlakte van oorblyfsels van die water in sekere sandstene help om die twee vernaamste migrasieroetes te kenmerk. 'n Hoogs omvattende koolwaterstof-korrelasieskema wat van gas, ligte olie en biomerkerdata verkry is, is opgestel. Die skema het onderskei tussen produkte van die vier aktiewe brongesteentes en help om die olie-olie, olie-bron en bron-bron pare te karakteriseer. Dit is duidelik van die korrelasies dat twee periodes van migrasie en opgaring plaasgevind het ongeveer teen -50-60 Ma en 0-10 Ma. Gevolglik kan bronreservoir omskrywings wat sekere dele van die kom karakteriseer as grotendeels olie of gas-ontvanklik beskryf word. Hierdie korrelasies beklemtoon ook areas waar mengsels van koolwaterstowwe algemeen voorkom en waar sekere van die vroeer opgegaarde olie verplaas is na nuwe lokaliteite, wat nuwe eksplorasieteikens daarstel. Brongesteentes vir sekere van die ge-analiseerde koolwaterstowwe, moet nog gevind word en is tot op hede nog nie raakgeboor nie. Een so 'n brongesteente kom voor in die Suidelike Outeniqua-kom, wat daardie area 'n potenslele teiken vir verdere eksplorasie maak. Die studie het die gesamentlike oorsprong van die brongesteente en reservoirsandsteen, wat deel is van die Outeniqua Petroleumsisteem, geidentifseer. Die koolwaterstofvolumes wat beskikbaar is vir die sisteem wys dat, gemeet teen wêreldstandaarde, dit wel beduidend is.
Moore, Myles Thomas. "Noble Gas and Hydrocarbon Geochemistry of Coalbed Methane Fields from the Illinois Basin." The Ohio State University, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=osu1462561493.
Full textMert-gauthier, Esra. "Modeling Permian Petroleum System Of Northeast Netherlands: Hydrocarbon Generation And Migration." Master's thesis, METU, 2010. http://etd.lib.metu.edu.tr/upload/12612508/index.pdf.
Full textAl-Arouri, Khaled R. "Petroleum geochemistry, source rock evaluation and modelling of hydrocarbon generation in the southern Taroom Trough, with particular reference to the Triassic Snake Creek Mudstone /." Title page, abstract and contents only, 1996. http://web4.library.adelaide.edu.au/theses/09PH/09pha321.pdf.
Full textNelson, Donald E. Jr. "Polycyclic Aromatic Hydrocarbons in Sediments of Marinas, Western Basin Lake Erie, U.S.A." University of Toledo / OhioLINK, 2009. http://rave.ohiolink.edu/etdc/view?acc_num=toledo1245342686.
Full textSerafini, K. M. "Hydrocarbon source rock potential of the Western Otway Basin : a geochemical and petrological study /." Title page, abstract and contents only, 1989. http://web4.library.adelaide.edu.au/theses/09SB/09sbs481.pdf.
Full textHrouda, Mohamed. "The hydrocarbon source potential of the palaeozoic rocks of the Ghadames Basin, NW Libya." Thesis, University of Newcastle Upon Tyne, 2005. http://hdl.handle.net/10443/1054.
Full textMcLaughlin, Fiona Ann. "The Canada basin, 1989-1995, upstream events and far-field effects of the Barents Sea branch." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2000. http://www.collectionscanada.ca/obj/s4/f2/dsk2/ftp03/NQ48224.pdf.
Full textNelson, Donald E. "Polycyclic aromatic hydrocarbons in sediments of marinas, Western Basin Lake Erie, U.S. A. /." Connect to full text in OhioLINK ETD Center, 2009. http://rave.ohiolink.edu/etdc/view?acc%5Fnum=toledo1245342686.
Full textTypescript. "Submitted as partial fulfillments of the requirements for The Master of Science in Geology." "A thesis entitled"--at head of title. Bibliography: leaves 99-109.
Mohammed, Muneef Mahjoob. "Stratal architecture and structural evolution of the Orange Basin, offshore Namibia : implications on hydrocarbon prospectivity." Thesis, University of Leeds, 2013. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.616299.
Full textRamirez-Caro, Daniel. "Rare earth elements (REE) as geochemical clues to reconstruct hydrocarbon generation history." Thesis, Kansas State University, 2013. http://hdl.handle.net/2097/16871.
Full textDepartment of Geology
Matthew Totten
The REE distribution patterns and total concentrations of the organic matter of the Woodford shale reveal a potential avenue to investigate hydrocarbon maturation processes in a source rock. Ten samples of the organic matter fraction and 10 samples of the silicate-carbonate fraction of the Woodford shale from north central Oklahoma were analyzed by methods developed at KSU. Thirteen oil samples from Woodford Devonian oil and Mississippian oil samples were analyzed for REE also. REE concentration levels in an average shale range from 170 ppm to 185 ppm, and concentration levels in modern day plants occur in the ppb levels. The REE concentrations in the organic matter of the Woodford Shale samples analyzed ranged from 300 to 800 ppm. The high concentrations of the REEs in the Woodford Shale, as compared to the modern-day plants, are reflections of the transformations of buried Woodford Shale organic materials in post-depositional environmental conditions with potential contributions of exchanges of REE coming from associated sediments. The distribution patterns of REEs in the organic materials normalized to PAAS (post-Archean Australian Shale) had the following significant features: (1) all but two out of the ten samples had a La-Lu trend with HREE enrichment in general, (2) all but two samples showed Ho and Tm positive enrichments, (3) only one sample had positive Eu anomalies, (4) three samples had Ce negative anomalies, although one was with a positive Ce anomaly, (5) all but three out of ten had MREE enrichment by varied degrees. It is hypothesized that Ho and Tm positive anomalies in the organic materials of the Woodford Shale are reflections of enzymic influence related to the plant physiology. Similar arguments may be made for the Eu and the Ce anomalies in the Woodford Shale organic materials. The varied MREE enrichments are likely to have been related to some phosphate mineralization events, as the Woodford Shale is well known for having abundant presence of phosphate nodules. The trend of HREE enrichment in general for the Woodford Shale organic materials can be related to inheritance from sources with REE-complexes stabilized by interaction between the metals and carbonate ligands or carboxylate ligands or both. Therefore, a reasonable suggestion about the history of the REEs in the organic materials would be that both source and burial transformation effects of the deposited organic materials in association with the inorganic constituents had an influence on the general trend and the specific trends in the distribution patterns of the REEs. This study provides a valuable insight into the understandings of the REE landscapes in the organic fraction of the Woodford Shale in northern Oklahoma, linking these understandings to the REE analysis of an oil generated from the same source bed and comparing it to oil produced from younger Mississippian oil. The information gathered from this study may ultimately prove useful to trace the chemical history of oils generated from the Woodford Shale source beds.
Salie, Sadiya. "The effects of minerals on reservoir properties in block 3A and 2C, within the orange basin, South Africa." University of the Western Cape, 2018. http://hdl.handle.net/11394/6588.
Full textThe reservoir quality of the Orange Basin, offshore South Africa is known to be immensely impaired by the presence of authigenic minerals. The collective effects of burial, bioturbation, compaction and chemical reactions between rocks, fluid and organic matter conclusively determined the quality of reservoirs within the Orange basin. The aim of this study was to provide information on the quality of reservoirs within the Orange Basin. Data used to conduct this study include wireline logs (LAS format), well completion reports and core samples from potential reservoir zones of wells K-A2, K-A3 and K-E1. To accomplish the aim, petrophysical parameters were calculated, such as porosity, permeability and water saturation. Besides, depositional environments were identified using gamma ray log and core logging techniques. Thirdly, petrographic studies were supporting techniques in understanding how various minerals and diagenetic processes play a role in reservoir characterisation. Geophysical wireline logs (Gamma ray, Resistivity, Bulk density and Caliper) allowed for the estimation of the three main reservoir properties; namely: porosity, water saturation and permeability. The porosity calculations revealed a range of 3-18% for well K-A2, 2%-13% for well K-A3 and 3%-16% for well K-E1. The permeability’s ranged from 0.08-0.1 mD and 0.001-1.30 mD for K-A3 and K-E1, respectively. Thus, the findings of the petrophysical evaluation of the wells in Interactive Petrophysics indicated that the reservoir intervals of wells K-A2, K-A3 and K-E1 are of poor to good quality. Based on the core analyses, the depositional environment is mostly shallow marine, specifically tide dominated for well K-A2, sandstone channel for well K-A3 and intertidal environment for well K-E1. These environments were confirmed by XRD, revealing glauconite as the prominent mineral.
Parker, Irfaan. "Petrophysical evaluation of sandstone reservoirs of the Central Bredasdorp Basin, Block 9, offshore South Africa." Thesis, University of the Western Cape, 2014. http://hdl.handle.net/11394/4661.
Full textThis contribution engages in the evaluation of offshore sandstone reservoirs of the Central Bredasdorp basin, Block 9, South Africa using primarily petrophysical procedures. Four wells were selected for the basis of this study (F-AH1, F-AH2, F-AH4, and F-AR2) and were drilled in two known gas fields namely F-AH and F-AR. The primary objective of this thesis was to evaluate the potential of identified Cretaceous sandstone reservoirs through the use and comparison of conventional core, special core analysis, wire-line log and production data. A total of 30 sandstone reservoirs were identified using primarily gamma-ray log baselines coupled with neutron-density crossovers. Eleven lithofacies were recognised from core samples. The pore reduction factor was calculated, and corrected for overburden conditions. Observing core porosity distribution for all wells, well F-AH4 displayed the highest recorded porosity, whereas well F-AH1 measured the lowest recorded porosity. Low porosity values have been attributed to mud and silt lamination influence as well as calcite overgrowths. The core permeability distribution over all the studied wells ranged between 0.001 mD and 2767 mD. Oil, water, and gas, were recorded within cored sections of the wells. Average oil saturations of 3 %, 1.1 %, and 0.2 % were discovered in wells F-AH1, F-AH2, and F-AH4. Wells F-AH1 to F-AR2 each had average gas saturations of 61 %, 57 %, 27 %, and 56 % respectively; average core water saturations of 36 %, 42 %, 27 %, and 44 % were recorded per well.
Mosavel, Haajierah. "Hydrocarbon potential of the Prince Albert Formation, Ecca Group in the main Karoo Basin, South Africa." University of the Western Cape, 2020. http://hdl.handle.net/11394/8342.
Full textThis thesis focusses on the hydrocarbon potential of the Prince Albert Formation in terms of its shale gas potential. Unconventional gas production from hydrocarbon-rich shale formations, known as “shale gas”, is one of the most rapidly expanding trends in onshore oil and gas exploration and exploitation today. In South Africa, the southern portion of the main Karoo Basin is potentially favourable for shale gas accumulation and may become a game changer in the energy production regime of the country. The Prince Albert Formation was selected for research, since previous studies in South Africa have focused on shale from the Whitehill Formation, which together with the underlying Prince Albert Formation, occur within the lower Ecca Group in the main Karoo Basin.
2023-08-16
Olajide, Oluseyi. "The petrophysical analysis and evaluation of hydrocarbon potential of sandstone units in the Bredasdorp Central Basin." Thesis, University of the Western Cape, 2005. http://etd.uwc.ac.za/index.php?module=etd&action=viewtitle&id=gen8Srv25Nme4_9559_1181561577.
Full textThis research was aimed at employing the broad use of petrophysical analysis and reservoir modelling techniques to explore the petroleum resources in the sandstone units of deep marine play in the Bredasdorp Basin.
Draper, Paul Christopher. "Secondary migration fairways and hydrocarbon potential of the Southern Enderby Terrace, Northern Carnarvon Basin, Western Australia /." Title page, contents and abstract only, 1995. http://web4.library.adelaide.edu.au/theses/09SB/09sbd766.pdf.
Full textTwo folded maps in pocket inside back cover. Includes bibliographical references (leaves 130-135).
Gray, Jayne L. "Aspects of hydrocarbon migration from a Permian coal seam in the southwest Cooper Basin, South Australia /." Title page, table of contents and abstract only, 1998. http://web4.library.adelaide.edu.au/theses/09SB/09sbg779.pdf.
Full textLondon, Jeremy Taylor. "Geologic Factors Affecting Hydrocarbon Occurrence in Paleovalleys of the Mississippian-Pennsylvanian Unconformity in the Illinois Basin." TopSCHOLAR®, 2014. http://digitalcommons.wku.edu/theses/1355.
Full textLasisi, Ayodele Oluwatoyin. "Pore pressure prediction and direct hydrocarbon indicator: insight from the southern pletmos basin, offshore South Africa." Thesis, University of the Western Cape, 2014. http://hdl.handle.net/11394/4255.
Full textAn accurate prediction of pore pressure is an essential in reducing the risk involved in a well or field life cycle. This has formed an integral part of routine work for exploration, development and exploitation team in the oil and gas industries. Several factors such as sediment compaction, overburden, lithology characteristic, hydrocarbon pressure and capillary entry pressure contribute significantly to the cause of overpressure. Hence, understanding the dynamics associated with the above factors will certainly reduce the risk involved in drilling and production. This study examined three deep water drilled wells GA-W1, GA-N1, and GA-AA1 of lower cretaceous Hauterivian to early Aptian age between 112 to 117.5 (MA) Southern Pletmos sub-basin, Bredasdorp basin offshore South Africa. The study aimed to determine the pore pressure prediction of the reservoir formation of the wells. Eaton’s resistivity and Sonic method are adopted using depth dependent normal compaction trendline (NCT) has been carried out for this study. The variation of the overburden gradient (OBG), the Effective stress, Fracture gradient (FG), Fracture pressure (FP), Pore pressure gradient (PPG) and the predicted pore pressure (PPP) have been studied for the selected wells. The overburden changes slightly as follow: 2.09g/cm3, 2.23g/cm3 and 2.24g/cm3 across the selected intervals depth of wells. The predicted pore pressure calculated for the intervals depth of selected wells GA-W1, GA-N1 and GA-AA1 also varies slightly down the depths as follow: 3,405 psi, 4,110 psi, 5,062 psi respectively. The overpressure zone and normal pressure zone were encountered in well GA-W1, while a normal pressure zone was experienced in both well GA-N1 and GA-AA1. In addition, the direct hydrocarbon indicator (DHI) was carried out by method of post-stack amplitude analysis seismic reflectors surface which was used to determine the hydrocarbon prospect zone of the wells from the seismic section. It majorly indicate the zones of thick hydrocarbon sand from the amplitude extraction grid map horizon reflectors at 13AT1 & 8AT1 and 8AT1 & 1AT1 of the well GA-W1, GA-N1 and GA-AA1 respectively. These are suggested to be the hydrocarbon prospect locations (wet-gas to Oil prone source) on the seismic section with fault trending along the horizons. No bright spot, flat spot and dim spot was observed except for some related pitfalls anomalies
Ward, Emily M. Geraghty. "Development of the Rocky Mountain foreland basin combined structural, mineralogical, and geochemical analysis of basin evolution, Rocky Mountain thrust front, northwest Montana /." CONNECT TO THIS TITLE ONLINE, 2007. http://etd.lib.umt.edu/theses/available/etd-09262007-094800/.
Full textMohammed, Saeed. "Geochemical evaluation of source rock potential and characterization of hydrocarbon occurrences in the Eastern Dahomey Basin, Nigeria." University of Western Cape, 2020. http://hdl.handle.net/11394/7929.
Full textNigeria is endowed with significant oil sand and heavy oil reserves. These reserves are found within the Cretaceous Afowo Formation in the Eastern Dahomey Basin. The petroleum systems and quality of these reserves are poorly understood. Harnessing these resources necessitate comprehensive deposit evaluation and characterization.
2023
Haselwood, Richard Franklin. "Aspects of the hydrocarbon potential of the Lockrose to Tamrookun section of the Clarence-Moreton Basin, Queensland." Thesis, Queensland University of Technology, 2003.
Find full textGaiennie, Edward Wilson Jr. "An Investigation into Secondary Migration of Hydrocarbons in the San Joaquin Basin Near Fresno, California." Thesis, University of Louisiana at Lafayette, 2019. http://pqdtopen.proquest.com/#viewpdf?dispub=10815005.
Full textProlific amounts of oil and gas have been produced from the San Joaquin Basin in many different oil and gas fields. In many cases, the petroleum system is easily identifiable, and the path hydrocarbons take from source area to trap are known. This study aims to identify secondary migration pathways of hydrocarbons from the source to the trap in an oil field near Fresno, California, where the source is about 35 miles from the trap. To create an accurate subsurface interpretation of the study area, 3D seismic data and more than 300 well logs were used. From subsurface structure maps, net sand maps, an Allan profile, and regional research, it was found that there are two possible migration scenarios that reasonably describe the secondary migration of hydrocarbons into the study area. Six normal faults within the field play large roles as seals and/or migration pathways, and to better understand hydrocarbon migration in the study area, further work must be done on the sealing/leaking behavior of the faults within the field.