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Letteratura scientifica selezionata sul tema "Hydrocarbon reservoirs"

Autore: Grafiati

Pubblicato: 4 giugno 2021

Ultima modifica: 1 agosto 2024

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Articoli di riviste sul tema "Hydrocarbon reservoirs"

Lü, Xiuxiang, Weiwei Jiao, Xinyuan Zhou, Jianjiao Li, Hongfeng Yu, and Ning Yang. "Paleozoic Carbonate Hydrocarbon Accumulation Zones in Tazhong Uplift, Tarim Basin, Western China." Energy Exploration & Exploitation 27, no. 2 (April 2009): 69–90. http://dx.doi.org/10.1260/0144-5987.27.2.69.

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Diverse types of marine carbonate reservoirs have been discovered in the Tazhong Uplift, Tarim Basin, and late alteration of such reservoirs is obvious. The marine source rocks of the Cambrian-lower Ordovician and the middle-upper Ordovician provided abundant oil and gas for hydrocarbon accumulation. The hydrocarbons filled various reservoirs in multiple stages to form different types of reservoirs from late Caledonian to early Hercynian, from late Hercynian to early Indosininan and from late Yanshanian to Himalayan. All these events greatly complicated hydrocarbon accumulation. An analysis of

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Li, Xiaoshan, Hong Pan, Yuxiao Wu, Guanxing Luo, Junqiang Song, Liu Yang, Kaifang Gu, et al. "Main Control Factors and Hydrocarbon Accumulation Model of Volcanic Oil Reservoirs with Complex Oil–Water Relationships: A Case Study of the Carboniferous in the Chepaizi Uplift, the Junggar Basin, China." Minerals 12, no. 11 (October 26, 2022): 1357. http://dx.doi.org/10.3390/min12111357.

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In order to study the main control factors of volcanic reservoirs with complex oil–water relationships, the Carboniferous in the Chepaizi Uplift of the Junggar Basin was taken as an example and the lithofacies characteristics, main control factors, and hydrocarbon accumulation model of volcanic reservoirs were investigated by combining the petroleum geology with field testing (data of core analysis, well logging, formation testing, and production testing). The results show that the Carboniferous in the Chepaizi Uplift experienced three stages of volcanic activities and developed seven volcanic

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Chen, Junqing, Xiongqi Pang, and Zhenxue Jiang. "Controlling factors and genesis of hydrocarbons with complex phase state in the Upper Ordovician of the Tazhong Area, Tarim Basin, China." Canadian Journal of Earth Sciences 52, no. 10 (October 2015): 880–92. http://dx.doi.org/10.1139/cjes-2014-0209.

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Seven hydrocarbon reservoirs have been discovered to date in the Upper Ordovician of the Tazhong Area, a region in which hydrocarbon phase distribution is complex. In the present study, the genesis and controlling factors of the hydrocarbons with complex phase in the Tazhong Area were investigated on the basis of the geological and geochemical conditions required for the formation and distribution of hydrocarbon reservoirs, integrated with the source rock geochemistry, natural gas and oil properties, and oil and gas reservoir fluid tests PVT (i.e., pressure, volume, and temperature tests). The

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Lerche, Ian. "Hydrocarbon Flow-up Intersecting Faults: Leakage/Production and Bypass Considerations." Energy Exploration & Exploitation 23, no. 4 (August 2005): 225–43. http://dx.doi.org/10.1260/014459805775219157.

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This article considers flow of hydrocarbons up a master fault that bifurcates and allows the hydrocarbons to enter or bypass reservoirs on either side of the bifurcated fault. In addition, leakage (or production) from each reservoir is allowed with a finite time span for the leakage. The rates of leakage from the two reservoirs are also allowed to be different so that the reservoirs either may fill, with concomitant bypass of excess hydrocarbons, or may be drained so rapidly by the leakage that they fill only partially. The timing of the leakage in respect of the timing of hydrocarbon fill is

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Ojo, Odunayo Tope. "Petrophysical and Geomechanical Analysis to Delineating Reservoirs in the Miocene Niger Delta Region of Nigeria." Geoinformatica Polonica 22 (December 1, 2023): 105–21. http://dx.doi.org/10.4467/21995923gp.23.009.18608.

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The application of various petrophysical and elastic metrics has advanced reservoir characterization and provided critical geological formation information. Porosity declines with depth, according to sonic, neutron, and density logs. Lithology, pressure, and hydrocarbons all contribute to this. Formation resistivity and fluid saturation are used to identify hydrocarbon-bearing zones. Because oil and gas are non-conductive, hydrocarbon-containing rocks are more resistant than water. In lithological categorization, gamma logs and the Vp/Vs ratio have helped classify reservoirs as Agbada Formatio

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Peng, Biao, Lulu Zhang, Jianfeng Li, Tiantian Chang, and Zheng Zhang. "Multi-Type Hydrocarbon Accumulation Mechanism in the Hari Sag, Yingen Ejinaqi Basin, China." Energies 15, no. 11 (May 27, 2022): 3968. http://dx.doi.org/10.3390/en15113968.

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With the successful development of unconventional hydrocarbons, the production of unconventional hydrocarbons has increased rapidly. However, a single conventional or unconventional model is not suitable for the mechanism of hydrocarbon accumulation in a given basin or sag. Based on data from drilling, logging, and geophysical analysis, the hydrocarbon accumulation mechanism in the Hari sag in the Yingen-Ejinaqi basin, China, was analyzed. There are three sets of source rocks in the Hari sag: the K1y source rocks were evaluated as having excellent source rock potential with low thermal maturit

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Mujakperuo, B. J. O., and O. J. Airen. "Pressure volume temperature evaluation of Sapele Field, Niger Delta, Southern Nigeria." Environmental Technology and Science Journal 15, no. 1 (June 24, 2024): 168–75. http://dx.doi.org/10.4314/etsj.v15i1.17.

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Sapele field is a large, brown field with complex subsurface structure that has led to heavy compartmentalization of its reservoirs which has also resulted to low reservoir pressure in some parts of the field leading to low production output. Reservoirs were delineated at various depth, some at near surface area (Benin formation) while others at greater depth (Agbada formation), hence the field was further subdivided into two (Sapele Shallow and Sapele Deep) due to its structural complexity. Pressure Volume Temperature (PVT) laboratory analysis on different wells was available for this study a

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Rashid, Muhammad, Miao Luo, Umar Ashraf, Wakeel Hussain, Nafees Ali, Nosheen Rahman, Sartaj Hussain, Dmitriy A. Martyushev, Hung Vo Thanh, and Aqsa Anees. "Reservoir Quality Prediction of Gas-Bearing Carbonate Sediments in the Qadirpur Field: Insights from Advanced Machine Learning Approaches of SOM and Cluster Analysis." Minerals 13, no. 1 (December 24, 2022): 29. http://dx.doi.org/10.3390/min13010029.

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The detailed reservoir characterization was examined for the Central Indus Basin (CIB), Pakistan, across Qadirpur Field Eocene rock units. Various petrophysical parameters were analyzed with the integration of various cross-plots, complex water saturation, shale volume, effective porosity, total porosity, hydrocarbon saturation, neutron porosity and sonic concepts, gas effects, and lithology. In total, 8–14% of high effective porosity and 45–62% of hydrocarbon saturation are superbly found in the reservoirs of the Eocene. The Sui Upper Limestone is one of the poorest reservoirs among all these

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Zhao, Shuangfeng, Wen Chen, Zhenhong Wang, Ting Li, Hongxing Wei, and Yu Ye. "Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China." Energy Exploration & Exploitation 36, no. 4 (February 22, 2018): 801–19. http://dx.doi.org/10.1177/0144598718759560.

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The condensate gas reservoirs of the Jurassic Ahe Formation in the Dibei area of the Tarim Basin, northwest China are typical tight sandstone gas reservoirs and contain abundant resources. However, the hydrocarbon sources and reservoir accumulation mechanism remain debated. Here the distribution and geochemistry of fluids in the Ahe gas reservoirs are used to investigate the formation of the hydrocarbon reservoirs, including the history of hydrocarbon generation, trap development, and reservoir evolution. Carbon isotopic analyses show that the oil and natural gas of the Ahe Formation originate

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Lerche, Ian. "Hydrocarbon Flow along Intersecting Faults." Energy Exploration & Exploitation 23, no. 2 (April 2005): 107–23. http://dx.doi.org/10.1260/0144598054529996.

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This paper is concerned with the channeling of hydrocarbon flow up a master fault and the diversion of the flow to the left or right at the intersection of the master fault with a second fault. In particular, when reservoirs of different capacities can exist on the master fault and the secondary fault, the question of the retention efficiency of the reservoirs to the hydrocarbon flow is of interest. In addition, given the customary lack of sharp knowledge of the hydrocarbon petroleum system before drilling, the influence of uncertainties in the flow and reservoir properties is discussed in ter

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Tesi sul tema "Hydrocarbon reservoirs"

Pereira, Leonardo Azevedo Guerra Raposo. "Seismic attributes in hydrocarbon reservoirs characterization." Master's thesis, Universidade de Aveiro, 2009. http://hdl.handle.net/10773/2735.

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Mestrado em Engenharia Geológica<br>No presente trabalho apresentam-se as vantagens da utilização de atributos sísmicos na interpretação de dados de sísmica de reflexão 3D e na identificação e caracterização de reservatórios de hidrocarbonetos. O trabalho prático necessário para a elaboração desta tese foi realizado durante um estágio de quatro meses na empresa de serviços para a indústria petrolífera, Schlumberger, em Paris, utilizando o software de interpretação sísmica e de modelação de reservatórios de hidrocarbonetos, Petrel 2008.1. Os atributos sísmicos podem ser considerados formas alte

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Taylor, Katherine Sarah. "Ephemeral-fluvial sediments as potential hydrocarbon reservoirs." Thesis, University of Aberdeen, 1994. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=123206.

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Although reservoirs formed from ephemeral-fluvial sandstones have previously been considered relatively simple, unresolved problems of sandbody correlation and production anomalies demonstrate the need for improved understanding of their internal complexity. Ephemeral flows occur in direct response to precipitation, receiving little or no water from springs or other long-continued sources. They consequently predominate in dryland regions where precipitation is high in intensity, short lived and of limited areal extent. Resulting flow is high energy, relatively shallow and also restricted in du

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Seth, Siddhartha. "Increase in surface energy by drainage of sandstone and carbonate." Laramie, Wyo. : University of Wyoming, 2006. http://proquest.umi.com/pqdweb?did=1221730011&sid=4&Fmt=2&clientId=18949&RQT=309&VName=PQD.

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Owens, John. "Using object-oriented databases to model hydrocarbon reservoirs." Thesis, University of Aberdeen, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.262174.

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Hydrocarbon reservoir modelling plays a central role in the exploration and production of reservoirs. This thesis describes significant improvements in the way that data and knowledge about reservoir modelling is used in comparison with other attempts at such modelling. This thesis describes the development of a flexible reservoir modelling environment which allows users to apply their own knowledge in order to influence the modelling process. The modelling environment allows users to explore their own 'What if ...' hypotheses. A Smalltalk/V functional data model has been used as a front end t

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Zoccarato, Claudia. "Data Assimilation in Geomechanics: Characterization of Hydrocarbon Reservoirs." Doctoral thesis, Università degli studi di Padova, 2016. http://hdl.handle.net/11577/3424496.

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The prediction of the stress field distribution induced by the pore pressure change in deep hydrocarbon reservoirs and the consequent compaction of the porous rock formation is modeled with the aid of a Finite-Element (FE) geomechanical model. Despite the reliability of the model, which has been tested in several previous applications, many sources of uncertainty may affect the model outcome in terms of ground surface displacements. The uncertainty are mainly related to the mathematical model itself, that is an approximation reproducing a real and complex system, the initial and boundary condi

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Fang, Chao. "Pore-scale Interfacial and Transport Phenomena in Hydrocarbon Reservoirs." Diss., Virginia Tech, 2019. http://hdl.handle.net/10919/89911.

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Exploring unconventional hydrocarbon reservoirs and enhancing the recovery of hydrocarbon from conventional reservoirs are necessary for meeting the society's ever-increasing energy demand and requires a thorough understanding of the multiphase interfacial and transport phenomena in these reservoirs. This dissertation performs pore-scale studies of interfacial thermodynamics and multiphase hydrodynamics in shale reservoirs and conventional oil-brine-rock (OBR) systems. In shale gas reservoirs, the imbibition of water through surface hydration into gas-filled mica pores was found to follow th

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Coffey, Melody Roy. "Microbially Mediated Porosity Enhancement in Carbonate Reservoirs: Experiments with samples from the Salem, Sligo, and Smackover Formations." MSSTATE, 2004. http://sun.library.msstate.edu/ETD-db/theses/available/etd-10122004-105856/.

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This study used petrographic thin sections, scanning electron microscopy, and confocal laser microscopy to document microbially mediated dissolution of carbonate reservoir rocks. The samples studied came from three carbonate units that are hydrocarbon reservoirs; the Salem, Sligo, and Smackover formations. These samples were inoculated with bacteria, and then treated with nutrient solutions followed by ethanol to promote generation of acetic acid by bacteria. Dissolution occurred in calcite-dominated rocks and in dolomitized rocks. Noticeable changes first occurred after nine weeks of ethanol

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Obidi, Onochie. "Timescales for the development of thermodynamic equilibrium in hydrocarbon reservoirs." Thesis, Imperial College London, 2014. http://hdl.handle.net/10044/1/24880.

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The full understanding of the initial state of petroleum reservoirs and the fluxes that lead to compositional variations have become of huge interest to the petroleum industry. The compositional variation of reservoir fluid has great commercial impact on reservoir management and field development as it affects the value of the hydrocarbon in place, what recovery mechanisms applied and the treatment process of the extracted fluid if necessary. Lateral and vertical variation in hydrocarbon density and composition between wells are observed in many oil reservoirs under appraisal. These gradations

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

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Key petrophysical properties of reservoir sequences are determined by their individual mineral compositions, and are routinely evaluated through the analysis of cores and geophysical well logs. However, mineralogical studies are seldom incorporated in reservoir assessment. The objectives of the study were to investigate the influence of mineralogy on petrophysical properties of petroleum reservoir beds and the application of mineralogical studies in reservoir evaluation. Mineralogical analyses were performed on core samples from the Plover Formation, the principal reservoir sequence in the Nor

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

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Più fonti

Libri sul tema "Hydrocarbon reservoirs"

Qiu, Yinan. Continental hydrocarbon reservoirs of China. Beijing: Petroleum Industry Press, 1997.

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Sydansk, Robert D. Reservoir conformance improvement. Richardson, TX: Society of Petroleum Engineers, 2011.

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Hazra, Bodhisatwa, Debanjan Chandra, and Vikram Vishal. Unconventional Hydrocarbon Reservoirs: Coal and Shale. Cham: Springer Nature Switzerland, 2024. http://dx.doi.org/10.1007/978-3-031-53484-3.

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American Association of Petroleum Geologists and American Association of Petroleum Geologists Foundation, eds. Lacustrine sandstone reservoirs and hydrocarbon systems. Tulsa, OK: American Association of Petroleum Geologists, 2012.

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Kerimov, V. I︠U︡. (Vagif I︠U︡nus ogly) and Gorfunkel Michael V, eds. Fluid dynamics of oil and gas reservoirs. Hoboken, New Jersey: Scrivener Publishing/Wiley, 2015.

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G, Bebout Don, Harris Paul M. 1949-, Society of Economic Paleontologists and Mineralogists. Permian Basin Section., University of Texas at Austin. Bureau of Economic Geology., and San Andres/Grayburg Research Conference and Field Trip (1986 : Midland, Tex.), eds. Geologic and engineering approaches in evaluation of San Andres/Grayburg hydrocarbon reservoirs--Permian Basin. Austin, Tex: Bureau of Economic Geology, University of Texas at Austin, 1990.

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I, Osipov V. Glinistye pokryshki nefti︠a︡nykh i gazovykh mestorozhdeniĭ. Moskva: Nauka, 2001.

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R, Braithwaite C. J., Rizzi G, Darke G, and Geological Society of London, eds. The geometry and petrogenesis of dolomite hydrocarbon reservoirs. London: Geological Society, 2004.

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Rocky Mountain Association of Geologists. Symposium. Compartmentalized reservoirs in Rocky Mountain Basins. Edited by Slatt Roger M. Denver, Colo: Rocky Mountain Association of Geologists, 1998.

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A, Robinson, and Geological Society of London, eds. The future of geological modelling in hydrocarbon development. London: Geological Society, 2008.

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Capitoli di libri sul tema "Hydrocarbon reservoirs"

Chierici, Gian Luigi. "Hydrocarbon Reservoirs." In Principles of Petroleum Reservoir Engineering, 1–16. Berlin, Heidelberg: Springer Berlin Heidelberg, 1994. http://dx.doi.org/10.1007/978-3-662-02964-0_1.

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Yu, Xinghe, Shengli Li, and Shunli Li. "Basic Features of Clastic Reservoirs." In Clastic Hydrocarbon Reservoir Sedimentology, 49–76. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-70335-0_3.

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Naqi, Mohammad, Ohood Alsalem, Suad Qabazard, and Fowzia Abdullah. "Petroleum Geology of Kuwait." In The Geology of Kuwait, 117–44. Cham: Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-031-16727-0_6.

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AbstractKuwait has proven conventional oil reserves of about 100 billion barrels which makes it one of the major oil-producing countries worldwide. Most of this reserve is found in Cretaceous and Jurassic with minor quantities in the Paleogene sedimentary successions. Most hydrocarbon production comes from the siliciclastic Burgan Formation which is the most important reservoir in Kuwait. The Jurassic and Lower Cretaceous exhibit good quality source rocks that charged most of the hydrocarbon reservoirs in Kuwait and entered the oil window in Late Cretaceous to Eocene. Most of the hydrocarbon is trapped in very gentle four-way closure structures that are related to the deep-seated fault system of the Arabian Peninsula such as Khurais-Burgan Anticline. Hydrocarbon reservoirs in Kuwait are sealed and capped mainly by shale rocks and to a less extent by evaporites. In the last 15 years, Kuwait Oil Company (KOC) displayed interest in commercially exploiting unconventional hydrocarbon reserves and started laying significant emphasis on the exploration and development of unconventional resources. The aim of this work is to summarize the different petroleum systems of Kuwait including the Paleozoic, Mesozoic, and Cenozoic systems.

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Head, I. M., S. R. Larter, N. D. Gray, A. Sherry, J. J. Adams, C. M. Aitken, D. M. Jones, A. K. Rowan, H. Huang, and W. F. M. Röling. "Hydrocarbon Degradation in Petroleum Reservoirs." In Handbook of Hydrocarbon and Lipid Microbiology, 3097–109. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-540-77587-4_232.

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Dou, Lirong, Kunye Xiao, and Jingchun Wang. "Geological Features of Hydrocarbon Reservoirs." In Petroleum Geology and Exploration of the Bongor Basin, 299–378. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-19-2673-0_7.

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Nanda, Niranjan C. "Fractured-Basement Reservoirs." In Seismic Data Interpretation and Evaluation for Hydrocarbon Exploration and Production, 293–304. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-75301-6_15.

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Karlsen, Dag A., and Steve Larter. "A rapid correlation method for petroleum population mapping within individual petroleum reservoirs: applications to petroleum reservoir description." In Correlation in Hydrocarbon Exploration, 77–85. Dordrecht: Springer Netherlands, 1989. http://dx.doi.org/10.1007/978-94-009-1149-9_8.

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Hazra, Bodhisatwa, Debanjan Chandra, and Vikram Vishal. "Potential for CO2 Sequestration in Coal and Shale." In Unconventional Hydrocarbon Reservoirs: Coal and Shale, 125–64. Cham: Springer Nature Switzerland, 2024. http://dx.doi.org/10.1007/978-3-031-53484-3_6.

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Hazra, Bodhisatwa, Debanjan Chandra, and Vikram Vishal. "Source-Rock Geochemistry of Unconventional Plays." In Unconventional Hydrocarbon Reservoirs: Coal and Shale, 9–34. Cham: Springer Nature Switzerland, 2024. http://dx.doi.org/10.1007/978-3-031-53484-3_2.

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Hazra, Bodhisatwa, Debanjan Chandra, and Vikram Vishal. "Estimation of Gas Storage Capacity Estimate in Coals and Shales." In Unconventional Hydrocarbon Reservoirs: Coal and Shale, 35–72. Cham: Springer Nature Switzerland, 2024. http://dx.doi.org/10.1007/978-3-031-53484-3_3.

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Atti di convegni sul tema "Hydrocarbon reservoirs"

Khan, Moin Uddin, and Jeffrey Guy Callard. "Reservoir Management in Unconventional Reservoirs." In SPE Hydrocarbon Economics and Evaluation Symposium. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/130146-ms.

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Alrassan, A. I., A. A. Al-Turki, and T. M. Al-Zahrani. "Data-Driven Approaches for Quick Performance Assessment of Hydrocarbon Reservoirs." In International Petroleum Technology Conference. IPTC, 2024. http://dx.doi.org/10.2523/iptc-23944-ms.

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Abstract Hydrocarbon reservoir's heterogeneity, production, injection and aquifer support play a unique role into how field strategies are developed knowing key reservoir properties (e.g. drainage volumes, reservoir energy, rock properties, decline analysis, etc.). Alanood et al. (2022) illustrated applications of Fast Marching Method (FMM) in assessing reservoir performance, identifying reservoir patterns and anomalies from production/injection data, and predicting the reservoir response when considering modeling uncertainty for model calibration. The objective of this paper is to extend the

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Wilson, S., A. Jupe, and W. Wason. "Microseismic Monitoring of Hydrocarbon Reservoirs." In 1st EAGE North African/Mediterranean Petroleum & Geosciences Conference & Exhibition. European Association of Geoscientists & Engineers, 2003. http://dx.doi.org/10.3997/2214-4609-pdb.8.t015.

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Jupe, A. J., and W. Wason. "Microseismic Monitoring of Hydrocarbon Reservoirs." In Geophysics of the 21st Century - The Leap into the Future. European Association of Geoscientists & Engineers, 2003. http://dx.doi.org/10.3997/2214-4609-pdb.38.f042.

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Rietveld, W. E. A., A. J. Berkhout, and C. P. A. Wapenaar. "Controlled illumination of hydrocarbon reservoirs." In SEG Technical Program Expanded Abstracts 1991. Society of Exploration Geophysicists, 1991. http://dx.doi.org/10.1190/1.1889125.

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Kome, Melvin, and Mohd Amro. "Water Influx Predictions in Reservoirs with Aquifer Drive Using the Two-Phase Reservoir Integral Type Pseudo-Pressure with Applicability in Gas Hydrate Reservoirs." In SPE/AAPG Africa Energy and Technology Conference. SPE, 2016. http://dx.doi.org/10.2118/afrc-2570887-ms.

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ABSTRACT The application of the Kirchhoff transformation has proven to be a very effective tool in simplifying and solving complex diffusivity equations in reservoirs. Since its introduction by [1] in addressing the non-linear behavior of compressible fluids, it has seen many modifications and implementations in multiphase systems, from the Perrine type pseudo-pressure to the reservoir integral type pseudo-pressure also called the Mass balance Model (MBM) for pseudo-pressure as discussed by [2]. Its applicability in addressing water influx from aquifers to oil and gas reservoirs has as of now

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Unalmiser, Servet, and T. J. Swalwell. "A Quick Technique To Define Compressibility Characteristics of Hydrocarbon Reservoir." In Low Permeability Reservoirs Symposium. Society of Petroleum Engineers, 1993. http://dx.doi.org/10.2118/25912-ms.

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F. Worthington, P. "Petrophysical Characterization of Complex Hydrocarbon Reservoirs." In 57th EAEG Meeting. Netherlands: EAGE Publications BV, 1995. http://dx.doi.org/10.3997/2214-4609.201409634.

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E. A. Rietveld, W., A. J. Berkhout, and C. P. A. Wapenaar. "Controlled seismic illumination of hydrocarbon reservoirs." In 53rd EAEG Meeting. European Association of Geoscientists & Engineers, 1991. http://dx.doi.org/10.3997/2214-4609.201411056.

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Makinde, Ibukun, and W. John Lee. "Production Forecasting in Shale Volatile Oil Reservoirs." In SPE/IAEE Hydrocarbon Economics and Evaluation Symposium. Society of Petroleum Engineers, 2016. http://dx.doi.org/10.2118/179965-ms.

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Rapporti di organizzazioni sul tema "Hydrocarbon reservoirs"

Michael Batzle. Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs. Office of Scientific and Technical Information (OSTI), April 2006. http://dx.doi.org/10.2172/898116.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS. Office of Scientific and Technical Information (OSTI), January 2005. http://dx.doi.org/10.2172/836821.

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Michael Batzle, D-h Han, R. Gibson, and Huw James. Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs. Office of Scientific and Technical Information (OSTI), January 2006. http://dx.doi.org/10.2172/876008.

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M. Batzle, D-h Han, R. Gibson, and O. Djordjevic. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS. Office of Scientific and Technical Information (OSTI), March 2003. http://dx.doi.org/10.2172/816390.

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Chidsey, Thomas C., David E. Eby, Michael D. Vanden Berg, and Douglas A. Sprinkel. Microbial Carbonate Reservoirs and Analogs from Utah. Utah Geological Survey, July 2021. http://dx.doi.org/10.34191/ss-168.

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Abstract (sommario):

Multiple oil discoveries reveal the global scale and economic importance of a distinctive reservoir type composed of possible microbial lacustrine carbonates like the Lower Cretaceous pre-salt reservoirs in deepwater offshore Brazil and Angola. Marine microbialite reservoirs are also important in the Neoproterozoic to lowest Cambrian starta of the South Oman Salt Basin as well as large Paleozoic deposits including those in the Caspian Basin of Kazakhstan (e.g., Tengiz field), and the Cedar Creek Anticline fields and Ordovician Red River “B” horizontal play of the Williston Basin in Montana and

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Cesar, J. R., and O. H. Ardakani. Organic geochemistry of the Montney Formation: new insights about the source of hydrocarbons, their accumulation history and post accumulation processes. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/329788.

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This study consists of a non-traditional molecular and stable isotope approach to analyze organic matter (soluble bitumen and produced oil/condensate) from the Montney Formation low-permeability reservoirs, with the purpose of identifying source(s) of hydrocarbons, accumulation history and post accumulation processes. The same approach bases on the distribution of compound classes such as aromatic carotenoids, polycyclic aromatic hydrocarbons (PAHs), bicyclic alkanes, and oxygen-polar compounds. The geochemical screening has been enhanced with performing compound specific isotope analysis (CSI

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Negri, M. Cristina. Microorganisms Associated with Hydrocarbon Contaminated Sites and Reservoirs for Microbially Enhanced Oil Recovery (MEOR). Office of Scientific and Technical Information (OSTI), October 2013. http://dx.doi.org/10.2172/1118140.

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Bosshart, Nicholas W., Scott C. Ayash, Nicholas A. Azzolina, Wesley D. Peck, Charles D. Gorecki, Jun Ge, Tao Jiang, et al. Optimizing and Quantifying CO₂ Storage Resource in Saline Formations and Hydrocarbon Reservoirs. Office of Scientific and Technical Information (OSTI), June 2017. http://dx.doi.org/10.2172/1367566.

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Steven B. Hawthorne. Subtask 1.17 - Measurement of Hydrocarbon Evolution from Coal and Petroleum Reservoirs Under Carbon Dioxide Floods. Office of Scientific and Technical Information (OSTI), December 2006. http://dx.doi.org/10.2172/922247.

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