Relevant bibliographies by topics / Petroleum reservoirs

Contents

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

Academic literature on the topic 'Petroleum reservoirs'

Author: Grafiati
Published: 4 June 2021
Last updated: 14 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'Petroleum reservoirs.'

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.

Journal articles on the topic "Petroleum reservoirs"

1

Roberts, D. G. "Sandstone petroleum reservoirs." Marine and Petroleum Geology 9, no. 1 (February 1992): 110. http://dx.doi.org/10.1016/0264-8172(92)90013-5.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Kulke, Holger. "Sandstone petroleum reservoirs." Sedimentary Geology 73, no. 3-4 (October 1991): 329–31. http://dx.doi.org/10.1016/0037-0738(91)90093-s.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Liu, Q., H. Xu, Z. Lei, Z. Li, Y. Xiong, S. Li, B. Luo, and D. Chen. "Fault Mesh Petroleum Plays in the Donghetang Area, Tabei Uplift, Tarim Basin, Northwestern China, and Its Significance for Hydrocarbon Exploration." Russian Geology and Geophysics 62, no. 07 (July 1, 2021): 808–27. http://dx.doi.org/10.2113/rgg20183939.

Full text
Abstract:
Abstract —The hydrocarbon formation mechanism and potential targets in clastic strata from the Tabei Uplift, Tarim Basin, are documented using the fault mesh petroleum plays theory, based on integrating seismic, well log, well core, and geochemical data. The reservoirs in the Donghetang area are typical allochthonous and far-source fault mesh petroleum plays. There are two sets of fault meshes in the study area: (1) the combination of the Donghe sandstone and Permian–Triassic strata and (2) the combination of the fourth and third formations in the Jurassic strata. The fault mesh petroleum play in the Jurassic is a secondary reservoir that originates from the Carboniferous Donghe sandstone reservoir adjustment based on source correlation. The fault mesh carrier systems show the fully connected, fault–unconformity–transient storage relay, fault–transient storage–unconformity relay, and transient storage–fault relay styles, according to the architecture of the fault mesh. Based on the characteristics of the fault mesh petroleum plays, the reservoirs are divided into three categories (upper-, inner-, and margin-transient storage styles) and 15 styles. Integrated analysis of the hydrocarbon generation and faulting time periods reveals that there were four periods of hydrocarbon charging, with the first three stages charging the reservoirs with oil and the last stage charging the reservoirs with gas. There are multiple stages of reservoir accumulation and adjustment in the fault mesh in the study area. These stages of fault mesh accumulation and adjustment are the main reason why the reservoir distribution multiple vertical units have different hydrocarbon properties. Fault-block and lithologic reservoirs related to the inner- and upper-transient storage styles are the main exploration targets in the clastic strata in the study area.
APA, Harvard, Vancouver, ISO, and other styles
4

Qin, Yaqiong, Zhaohui Ye, and Conghui Zhang. "Application of deep learning for division of petroleum reservoirs." MATEC Web of Conferences 246 (2018): 03004. http://dx.doi.org/10.1051/matecconf/201824603004.

Full text
Abstract:
Traditional methods of dividing petroleum reservoirs are inefficient, and the accuracy of onehidden-layer BP neural network is not ideal when applied to dividing reservoirs. This paper proposes to use the deep learning models to solve the reservoir division problem. We apply multiple-hidden-layer BP neural network and convolutional neural network models, and adjust the network structures according to the characteristics of the reservoir problem. The results show that the deep learning models are better than onehidden- layer BP neural network, and the performance of the convolutional neural network is very close to the artificial work.
APA, Harvard, Vancouver, ISO, and other styles
5

Li, Dongmei, and Philip Hendry. "Microbial diversity in petroleum reservoirs." Microbiology Australia 29, no. 1 (2008): 25. http://dx.doi.org/10.1071/ma08025.

Full text
Abstract:
Buried hydrocarbon deposits, such as liquid petroleum, represent an abundant source of reduced carbon for microbes. It is not surprising therefore that many organisms have adapted to an oily, anaerobic life deep underground, often at high temperatures and pressures, and that those organisms have had, and in some cases continue to have, an effect on the quality and recovery of the earth?s diminishing petroleum resources. There are three key microbial processes of interest to petroleum producers: reservoir souring, hydrocarbon degradation and microbially enhanced oil recovery (MEOR).
APA, Harvard, Vancouver, ISO, and other styles
6

Hasan, Agus. "Optimal Control of Petroleum Reservoirs." IFAC Proceedings Volumes 46, no. 26 (2013): 144–49. http://dx.doi.org/10.3182/20130925-3-fr-4043.00055.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Selley, R. C. "Exploration for Carbonate Petroleum Reservoirs." Sedimentary Geology 43, no. 1-4 (April 1985): 310–11. http://dx.doi.org/10.1016/0037-0738(85)90065-x.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Wang, L. Y., R. Y. Duan, J. F. Liu, S. Z. Yang, J. D. Gu, and B. Z. Mu. "Molecular analysis of the microbial community structures in water-flooding petroleum reservoirs with different temperatures." Biogeosciences 9, no. 11 (November 20, 2012): 4645–59. http://dx.doi.org/10.5194/bg-9-4645-2012.

Full text
Abstract:
Abstract. Analyses of microbial communities from six water-flooding petroleum reservoirs at temperatures from 21 to 63 °C by 16S rRNA gene clone libraries indicates the presence of physiologically diverse and temperature-dependent microorganisms in these subterrestrial ecosystems. In samples originating from high-temperature petroleum reservoirs, most of the archaeal sequences belong to thermophiles affiliated with members of the genera Thermococcus, Methanothermobacter and the order Thermoplasmatales, whereas bacterial sequences predominantly belong to the phyla Firmicutes, Thermotogae and Thermodesulfobacteria. In contrast to high-temperature petroleum reservoirs, microorganisms belonging to the Proteobacteria, Methanobacteriales and Methanomicrobiales were the most encountered in samples collected from low-temperature petroleum reservoirs. Canonical correspondence analysis (CCA) revealed that temperature, mineralization, ionic type as well as volatile fatty acids showed correlation with the microbial community structures, in particular members of the Firmicutes and the genus Methanothermobacter showed positive correlation with temperature and the concentration of acetate. Overall, these data indicate the large occurrence of hydrogenotrophic methanogens in petroleum reservoirs and imply that acetate metabolism via syntrophic oxidation may represent the main methanogenic pathway in high-temperature petroleum reservoirs.
APA, Harvard, Vancouver, ISO, and other styles
9

Yang, Guang-Chao, Lei Zhou, Serge Mbadinga, Ji-Dong Gu, and Bo-Zhong Mu. "Bioconversion Pathway of CO2 in the Presence of Ethanol by Methanogenic Enrichments from Production Water of a High-Temperature Petroleum Reservoir." Energies 12, no. 5 (March 9, 2019): 918. http://dx.doi.org/10.3390/en12050918.

Full text
Abstract:
Transformation of CO2 in both carbon capture and storage (CCS) to biogenic methane in petroleum reservoirs is an attractive and promising strategy for not only mitigating the greenhouse impact but also facilitating energy recovery in order to meet societal needs for energy. Available sources of petroleum in the reservoirs reduction play an essential role in the biotransformation of CO2 stored in petroleum reservoirs into clean energy methane. Here, the feasibility and potential on the reduction of CO2 injected into methane as bioenergy by indigenous microorganisms residing in oilfields in the presence of the fermentative metabolite ethanol were assessed in high-temperature petroleum reservoir production water. The bio-methane production from CO2 was achieved in enrichment with ethanol as the hydrogen source by syntrophic cooperation between the fermentative bacterium Synergistetes and CO2-reducing Methanothermobacter via interspecies hydrogen transfer based upon analyses of molecular microbiology and stable carbon isotope labeling. The thermodynamic analysis shows that CO2-reducing methanogenesis and the methanogenic metabolism of ethanol are mutually beneficial at a low concentration of injected CO2 but inhibited by the high partial pressure of CO2. Our results offer a potentially valuable opportunity for clean bioenergy recovery from CCS in oilfields.
APA, Harvard, Vancouver, ISO, and other styles
10

Aguilera, Roberto. "Flow Units: From Conventional to Tight-Gas to Shale-Gas to Tight-Oil to Shale-Oil Reservoirs." SPE Reservoir Evaluation & Engineering 17, no. 02 (February 20, 2014): 190–208. http://dx.doi.org/10.2118/165360-pa.

Full text
Abstract:
Summary Core data from various North American basins with the support of limited amounts of data from other basins around the world have shown in the past that process speed or delivery speed (the ratio of permeability to porosity) provides a continuum between conventional, tight-, and shale-gas reservoirs (Aguilera 2010a). This work shows that the previous observation can be extended to tight-oil and shale-oil reservoirs. The link between the various hydrocarbon fluids is provided by the word “petroleum” in the “total petroleum system (TPS),” which encompasses liquid and gas hydrocarbons found in conventional, tight, and shale reservoirs. Results of the present study lead to distinctive flow units for each type of reservoir that can be linked empirically to gas and oil rates and, under favorable conditions, to production decline. To make the work tractable, the bulk of the data used in this paper has been extracted from published geologic and petroleum-engineering literature. The paper introduces an unrestricted/transient/interlinear transition flow period in a triple-porosity model for evaluating the rate performance of multistage-hydraulically-fractured (MSHF) tight-oil reservoirs. Under ideal conditions, this flow period is recognized by a straight line with a slope of –1.0 on log-log coordinates. However, the slope can change (e.g., to –0.75), depending on reservoir characteristics, as shown with production data from the Cardium and Shaunavon formations in Canada. This interlinear flow period has not been reported previously in the literature because the standard assumption for MSHF reservoirs has been that of a pseudosteady-state transition between the linear flow periods. It is concluded that there is a significant practical potential in the use of process speed as part of the flow-unit characterization of unconventional petroleum reservoirs. There is also potential for the evaluation of production-decline rates by the use of the triple-porosity model presented in this study.
APA, Harvard, Vancouver, ISO, and other styles
More sources

Dissertations / Theses on the topic "Petroleum reservoirs"

1

Yacob, Shahrakbah, and n/a. "Metal-reducing microorganisms in petroleum reservoirs." University of Canberra. Resource & Environmental Science, 2000. http://erl.canberra.edu.au./public/adt-AUC20061112.102729.

Full text
Abstract:
Metal-reducing microorganisms reduce a variety of metals in metabolic processes coupled to the oxidation of organic compounds. These bacteria play an important role in the biogeochemical cycling of metals and organic matter in anaerobic aquatic and sediment ecosystems. It has been proposed recently that metal-reducing microorganisms also are active in deep subsurface environments such as petroleum reservoirs. Only two metal-reducing bacteria have been isolated from petroleum reservoir fluids, Shewanella putrefaciens and Deferribacter thermophilus. This project studied the occurrence and distribution of metal-reducing microorganisms in petroleum reservoirs. The research focused on the isolation, characterisation and identification of anaerobic bacteria from petroleum reservoirs that were capable of reducing metals and the potential roles of these isolates in the microbial ecology and biogeochemical cycling of petroleum reservoirs. Petroleum reservoirs were selected for this study on the basis of physio-chemical conditions such as temperature, salinity, pH and the presence of organic and inorganic compounds, that were likely to provide a suitable environment for anaerobic bacteria capable of reducing metals. Factors such as the stratigraphic features of the sedimentary basin, age of reservoir and past oil field practices also were considered in choosing the reservoir for study. Seven petroleum reservoirs in the USA and Azerbaijan were chosen for extensive investigations. The physico-chemical conditions in these reservoirs varied substantially. A systematic study of the production water from these petroleum reservoirs revealed a consistent presence of iron- and manganese-reducing microorganisms. It was found that salinity and temperature play a significant and defining role in the occurrence and distribution of these metal-reducing microorganisms. Biotic metal reduction was detected from production waters from all but one of the oil wells sampled. It was significant that the water from this well (Neftcala #1074) was the most saline (78 g/l NaCI). Metal-reducing activity was detected at temperatures up to 70°C. Two pure cultures, strains RED1 for Redwash petroleum reservoir (USA) and NEF1 from the Neftcala petroleum reservoir (Azerbaijan) were isolated and characterized. The strains had diverse physiological and metabolic properties including the ability to oxidize a wide range of carbon compounds and reduce a variety of metals. Their temperature, salinity and pH optima varied markedly. Phylogenetic analyses of the 16S rRNA of strain RED1 showed that the strain represented a new species of a new genus in the domain Bacteria. The bacterium most closely related to strain RED1 is the fermentative Fe(III)-reducer, Pelobacter acetylenicus (similarity value, 92.8%). Strain NEF1 possesses a unique combination of phenotypic traits and a low mol % G+C. From preliminary analyses and comparative biochemistry, NEF1 appears to be a novel metal-reducing bacterium of the Flexistipes group. The bacteria isolated in this study were able to grow at temperatures and salinities consistent with the reservoir from which they were isolated. This indicated that petroleum reservoirs are a new source of physiologically diverse, novel, metal-reducing microorganisms. The bacteria isolated also demonstrated a number of characteristics that would enable them to survive and persist in extreme subsurface conditions and develop a selective ecological advantage in petroleum reservoir environments. Significantly, the metal-reducing bacteria isolated were able to utilize an array of metabolic products produced by bacteria indigenous to petroleum reservoirs. This has resulted in a new proposed model for the ecological succession of bacteria in petroleum reservoirs.
APA, Harvard, Vancouver, ISO, and other styles
2

SOUZA, ANTONIO LUIZ SERRA DE. "STUDY OF HEAT LOSSES IN PETROLEUM RESERVOIRS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 1988. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=20366@1.

Full text
Abstract:
PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
PETRÓLEO BRASILEIRO S. A.
Neste trabalho analisam-se perdas de calor para as formações adjacentes a reservatórios de petróleo submetidos a métodos térmicos de recuperação, em especial para os métodos de injeção de vapor e combustão in-situ. O cálculo desta perda usualmente utiliza um modelo unidimensional vertical de condução de calor nos estratos adjacentes, desprezando a condução nas direções paralelas ao reservatório. O objetivo do trabalho consiste em avaliar diversos modelos unidimensionais existentes na literatura e desenvolver e utilizar modelos bidimensionais para verificar a validade da hipótese. Verifica-se que para algumas situações de injeção Cíclica de Vapor e Combustão in-situ o modelo uni-dimensional pode levar a diferenças no campo de temperaturas, mas em geral a aproximação é válida.
In this work the calculation of the heat losses to the surrouinding formations in petrolum reservouis submitted to thermal recovery processes is analyzed. Particular attention is given to steam injection an in-situ combustion methods. The heat losses are commonly modeled by the use of a unidimensional conduction equation in the vertical direction, where the longitudinal conduction is neglected. The aim of thus work is to compare some of the existing unidemnsional models and to test the validity of the simplification by the development and use of bidimensional ones. Its is concluded that for some cases of cyclic steam injection and in-situ combustion the unidimensional approach may result in deviations in the temperature profiles, but in general it is valid.
APA, Harvard, Vancouver, ISO, and other styles
3

Grassia, Gino Sebastian, and n/a. "The isolation, growth and survival of thermophilic bacteria from high temperature petroleum reservoirs." University of Canberra. Applied Science, 1995. http://erl.canberra.edu.au./public/adt-AUC20060712.131412.

Full text
Abstract:
The microbial ecology of 45 high temperature (> 50 ° C) petroleum reservoirs was investigated by isolating and characterizing bacteria that were present in their produced fluids. Initial work was aimed at selecting a suitable high temperature petroleum reservoir for the study of natural microbial populations. Experimental work then focussed on establishing the physico-chemical conditions that prevail in the selected reservoir and on developing media and enrichment conditions for the isolation of microorganisms indigenous to the reservoir. The ability of reservoir bacteria to grow and survive under the physical and chemical conditions found in the selected reservoir was used to assess the likelihood of an indigenous origin for these bacteria. The petroleum reservoir selected for study was the Alton petroleum reservoir (SW Queensland, Australia). It was established that most of the physico-chemical conditions in the Alton reservoir had remained unchanged since oil recovery began. The stability of redox conditions (90 mV) in the reservoir over its operating life was identified as an important factor in the coexistence of strict aerobic and strict anaerobic bacterial populations within the reservoir. An important change that has occurred in the Alton reservoir over its operating life because of oil recovery was an increase in water pH from 6.41 to 8.42 as a result of carbon dioxide loss (1.36 atm to 0.0134 atm) from the reservoir. Development of novel enrichment procedures that simulated Alton reservoir conditions led to the isolation of previously unreported aerobic and anaerobic populations of thermophilic bacteria. The aerobic bacteria isolated were identified as either endosporeforming heterotrophic bacteria from the genus Bacillus or nonspore-forming heterotrophic bacteria resembling members of the genus Thermoleophilum. All aerobes grew on carbon sources such as acetate and n-heptadecane that are normal constituents of the reservoir. The anaerobic bacteria isolated were characterized as sheathed fermentative bacteria from the order Thermotogales or non-sheathed fermentative bacteria. In parallel studies, the natural microbial populations in other reservoirs were investigated and I concluded that fermentative microorganisms were common inhabitants of high temperature petroleum reservoirs. The isolation of fermentative bacteria from these high temperature petroleum reservoirs established that fermentative bacteria are a fourth major microbial group, together with hydrocarbon-oxidizers, sulphate-reducers and methanogens, to be reported in petroleum reservoirs. The fermentative bacteria use organic nutrients and carbohydrates, but not contemporary crude oil as the principal nutrient source within reservoir waters. The thermophilic bacteria isolated from Alton petroleum reservoir demonstrated growth characteristics such as temperature (optima 50-70 ° C and range 37-85 ° C), pH (optima 6.0-9.0 and range 5.0-9.0 and salinity (optima 0-15 g per litre and range 0-30 g per litre), that were consistent with conditions encountered in the Alton reservoir (temperature 75 � C, pH 8.5 and TDS 2.7 g per litre). The isolated bacteria also demonstrated a number of characteristics that might enable them to survive adverse conditions that could be encountered in a petroleum reservoir environment. The characteristics that contribute to aerobic bacteria surviving in and overcoming periods of oxygen limitation include well-documented processes such as sporulation, by Bacillus spp., and microaerophily. The characteristics that contribute to fermentative bacteria surviving were: (1) a natural tolerance to reservoir physico-chemical fluctuations, (2) an ability to remain viable when metabolic activity was suppressed to very low rates by the growth-limiting conditions imposed, and (3) possible formation of viable ultramicrobacteria (UMB). Formation of UMB (bacteria smaller than 0.3 |im) by thermophilic bacteria has not been reported previously. The recovery of thermophilic UMB by filtration from the Alton reservoir water indicates that these bacteria occur in natural habitats. This study found the formation of thermophilic UMB and their survival characteristics differed considerably from that reported for the mesophilic, marine bacterium Vibrio sp. DWI. Unlike mesophilic marine bacteria, thermophilic bacteria did not always respond to nutrient deprivation by forming UMB and that these UMB did not show any increased ability to survive in the face of adverse conditions. Although the formation of UMB as part of routine cell growth and division was not demonstrated directly in this study, circumstantial evidence suggests that they form part of a natural life cycle. The exact conditions that result in UMB formation and their role in survival remain unresolved. The capacity of nonspore-forming indigenous populations from Alton to survive sudden shifts in environmental conditions that might result from common oilfield operations was poor. Such operations were demonstrated to be inhibitory or lethal to Alton reservoir bacteria. It also was concluded that such oilfield operations suppress indigenous microbiota. However, the impacts of most oilfield operations within a reservoir are likely to be confined to the immediate area surrounding injection and producing wells. Minimizing the localized effects of oilfield practices on indigenous reservoir populations will lead to the better management of undesirable microbial activity in reservoirs such as H2S formation (souring) and facilitate development of better microbially mediated oil recovery process. This study showed that selected reservoir isolates possess characteristics which are suitable for in situ biotechnological applications such as microbially enhanced oil recovery (MEOR). Characteristics favourable for enhanced oil recovery include a capability for UMB formation, which would enable better dispersion, and resistance to high concentrations of reservoir components such as calcium, magnesium, strontium, heavy metals and hydrocarbons.
APA, Harvard, Vancouver, ISO, and other styles
4

Alkafeef, Saad Feheid. "A study of colloidal asphaltene in petroleum reservoirs." Thesis, Imperial College London, 1997. http://hdl.handle.net/10044/1/11246.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Hooper, Heather J. (Heather Julie) 1975. "Analysis and modeling of induced seismicity in petroleum reservoirs." Thesis, Massachusetts Institute of Technology, 2002. http://hdl.handle.net/1721.1/54445.

Full text
Abstract:
Thesis (S.M. in Geosystems)--Massachusetts Institute of Technology, Dept. of Earth, Atmospheric, and Planetary Sciences, 2002.
Includes bibliographical references (p. 53).
Since 1998, a producing oil field in Oman has been experiencing microearthquake activity. The aim of this project is to compare numerical models of wave propagation using simple source representations to a small subset of these microearthquakes, with three goals in mind: 1) to understand whether the microearthquakes are generated by movement along a known fault system in the field, or by some other mechanism; 2) if the source is fault related, to better understand what kind of movement is occurring on the fault; and 3) to see if this simple modeling method provides useful results, and forms a basis for future work. Synthetic waveforms are generated using a one-dimensional, discrete wavenumber numerical model (Bouchon, 1980) with two simple source representations: an explosive point source and a vertical force. Comparison of the synthetic waveforms to the microearthquake data indicates that the vertical force results in a better match than the explosive point source. In addition, a simple model consisting of the superposition of four vertical forces (representing vertical fault rupture), results in waveforms that are very similar to the recorded events. These results suggest that the source of the microearthquakes is motion along a near-vertical normal fault system that has been mapped in the field. These results are also consistent with work by Sze and Toksoz (2001) in which relocation of the same events imaged a near-vertical normal fault in the field. Further work using fault rupture source modeling may provide additional insight into the amount of fault motion that is occurring in relation to these events.
by Heather J. Hooper.
S.M.in Geosystems
APA, Harvard, Vancouver, ISO, and other styles
6

Houston, Stephanie Jane. "Formation waters in petroleum reservoirs : their controls and applications." Thesis, University of Leeds, 2007. http://etheses.whiterose.ac.uk/1063/.

Full text
Abstract:
Abundant water chemistry analyses from nine different locations (predominantly petroleum reservoirs) on five continents were evaluated. This information, together with local mineralogy, depth and temperature relations provided a sound basis from which to investigate the most important controls on formation water composition. In particular, the detailed study of two very different hydrocarbon reservoir case studies (the Central US coalbed methane reservoir, the San Juan Basin and the North Sea oilfield Miller) provided an insight not only into the fundamental controls on formation water composition, but also into the effects of active oilfield development on systems that are very sensitive to change on rapid timescales. The geochemistry of San Juan waters is controlled by the introduction of bicarbonate through carbonate dissolution and methane/coal oxidation leading to leaching of Na-bearing clay minerals, and by ion exchange on clay minerals and dilution by meteoric waters in certain locations. The time series of produced waters from Miller enabled detailed study of fluid mixing in the field and the physical, chemical and thermodynamic response of the system to the injection of seawater. Changes occur in the concentrations of many water components through time that cannot be explained by linear mixing between formation water and injected water and require dissolution or precipitation reactions to have occurred between injection and production sites. For example Ba, and SO4 concentrations are affected by equilibrium with barite and what is likely to be sulphate reduction. Also, excess Si present in the fluid is due to dissolution of the silicate phases in the reservoir, and demonstrates reactions between silicate minerals occur on a fast enough timescale to buffer the pH of the water. Integration of all available data shows consistent patterns of behaviour, which implicate mineral-fluid interactions in the subsurface as a major control on formation water chemistry. For example, globally, Ca concentrations are shown to behave in one of three ways, all of which depend on water interaction with the host rock, be it silicate or carbonate, clastic or evaporite. Distinct trends arise for bicarbonate waters, brines derived by halite dissolution and formation brines that have evolved extensively with silicates. In addition, K concentrations are closely related to feldspar-clay equilibria and Mg concentrations are influenced predominantly by carbonate minerals with significant contribution from clays. It is likely that initial Ba concentration is related to interaction with K-feldspars and SO4 is controlled by equilibrium with sulphate mineral phases as well as by redox. A greater understanding of formation water chemistry leads to an improved perception of the importance of these systems in terms of both furthering scientific progress and the technological development of the oil and gas industry. In particular, produced water chemistry analyses from Miller were used to appraise and improve the most important aspects of both generic and specific reservoir models. A set of simple models emphasised the point that small variations in reservoir property parameters can have significant effects on model outputs, and thus the highlighted the importance of thorough reservoir characterisation, particularly permeability heterogeneity, capillary pressure and relative fluid permeabilities. Geochemical models of three different systems from the integrated database (the Alberta Basin, a Colombian onshore oilfield and an oilfield from offshore Gulf of Mexico) illustrate that reservoir rocks containing a wide variety of minerals are the most effective at limiting pH decrease following the injection of CO2 into the system. The geochemistry, in particular the salinity, of the formation water present also has a significant bearing on the processes that are likely to occur during CO2 sequestration.
APA, Harvard, Vancouver, ISO, and other styles
7

Jenkins, C. C. "The organic geochemical correlation of crude oils from early Jurassic to late Cretaceous Age reservoirs of the Eromanga Basin and late Triassic Age reservoirs of the underlying Cooper Basin /." Title page, contents and abstract only, 1987. http://web4.library.adelaide.edu.au/theses/09SM/09smj521.pdf.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Abdulla, Fawzeiah Hussien Ali. "Source rock evaluation and maturity studies of Lower and Middle Cretaceous formations in Kuwait." Thesis, Imperial College London, 1993. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.312472.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Ngah, Khalid Bin. "Deposition and diagenesis of Oligocene-Lower Miocene sandstones in the southern Malay Basin." Thesis, Imperial College London, 1990. http://hdl.handle.net/10044/1/46470.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

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.

Full text
Abstract:
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 duration and areal coverage. High transmission losses, abundant loose material and sparse vegetation result in highly concentrated flows which dissipate rapidly, causing a downstream decrease in flow discharge. Sediments deposited from these flows include parallel laminated sands, massive sands, scour-fill sands, transitional lower to upper flow regime dunes, and commonly contain numerous erosional discontinuities, scattered mudclasts, rapid grain size changes and deformational features. Large quantities of rainfall falling over longer periods produces steady flows dominated by well sorted, lower flow regime bedforms which have moderately well developed fining-up sequences. High intensity rainfall falling for shorter periods produces unsteady flows which are characterised by more poorly sorted, upper flow regime bedforms and an absence of fining-up sequences. Outcropping ephemeral-fluvial systems have been studied in order to determine the main features and processes occurring in sand-rich ephemeral systems and to identify which features will be of importance in a hydrocarbon reservoir. The Lower Jurassic Upper Moenave and Kayenta Formations of south-eastern Utah and northern Arizona comprise complex series of stacked, sand-dominated sheet-like palaeochannels suggestive of low sinuosity, braided systems.
APA, Harvard, Vancouver, ISO, and other styles
More sources

Books on the topic "Petroleum reservoirs"

1

Roehl, Perry O., and Philip W. Choquette, eds. Carbonate Petroleum Reservoirs. New York, NY: Springer New York, 1985. http://dx.doi.org/10.1007/978-1-4612-5040-1.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Barwis, John H., John G. McPherson, and Joseph R. J. Studlick, eds. Sandstone Petroleum Reservoirs. New York, NY: Springer New York, 1990. http://dx.doi.org/10.1007/978-1-4613-8988-0.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Leonard, Koederitz, and Harvey A. Herbert, eds. Relative permeability of petroleum reservoirs. Boca Raton, Fla: C.R.C. Press, 1986.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
4

Petroleum geology and reservoirs. 2nd ed. Austin, Tex: Petroleum Extension Service, University of Texas at Austin, 1992.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
5

Hu, Xuetao, Shuyong Hu, Fayang Jin, and Su Huang, eds. Physics of Petroleum Reservoirs. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-53284-3.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Hu, Xuetao, Shuyong Hu, Fayang Jin, and Su Huang, eds. Physics of Petroleum Reservoirs. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-55026-7.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Principles of petroleum reservoir engineering. Berlin: Springer-Verlag, 1994.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
8

Naturally fractured reservoirs. 2nd ed. Tulsa, Okla: PennWell Books, 1995.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
9

Pápay, József. Development of petroleum reservoirs: Theory and practice. Budapest: Akadémiai Kiadó, 2003.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
10

1955-, Spivey John Paul, and Lenn Christopher P, eds. Petroleum reservoir fluid property correlations. Tulsa, Okla: PennWell Corp., 2010.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
More sources

Book chapters on the topic "Petroleum reservoirs"

1

Archer, J. S., and C. G. Wall. "Reservoirs." In Petroleum Engineering, 7–19. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_2.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Ganat, Tarek Al-Arbi Omar. "Unconventional Petroleum Reservoirs." In Fundamentals of Reservoir Rock Properties, 115–29. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-28140-3_8.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Bjørlykke, Knut, and Jens Jahren. "Sandstones and Sandstone Reservoirs." In Petroleum Geoscience, 113–40. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_4.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Bjørlykke, Knut, and Jens Jahren. "Sandstones and Sandstone Reservoirs." In Petroleum Geoscience, 119–49. Berlin, Heidelberg: Springer Berlin Heidelberg, 2015. http://dx.doi.org/10.1007/978-3-642-34132-8_4.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

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.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Planckaert, Marie. "Oil Reservoirs and Oil Production." In Petroleum Microbiology, 1–19. Washington, DC, USA: ASM Press, 2014. http://dx.doi.org/10.1128/9781555817589.ch1.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Huang, Haiping, and Steve Larter. "Biodegradation of Petroleum in Subsurface Geological Reservoirs." In Petroleum Microbiology, 89–121. Washington, DC, USA: ASM Press, 2014. http://dx.doi.org/10.1128/9781555817589.ch6.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Jin, Fayang. "Principles of Enhanced Oil Recovery." In Physics of Petroleum Reservoirs, 465–506. Berlin, Heidelberg: Springer Berlin Heidelberg, 2016. http://dx.doi.org/10.1007/978-3-662-53284-3_5.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Hu, Xuetao, and Su Huang. "Introduction." In Physics of Petroleum Reservoirs, 1–6. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-55026-7_1.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

Hu, Xuetao, and Su Huang. "Physical Properties of Reservoir Rocks." In Physics of Petroleum Reservoirs, 7–164. Berlin, Heidelberg: Springer Berlin Heidelberg, 2017. http://dx.doi.org/10.1007/978-3-662-55026-7_2.

Full text
APA, Harvard, Vancouver, ISO, and other styles

Conference papers on the topic "Petroleum reservoirs"

1

Shedid, S. A., and R. A. Almehaideb. "Enhanced Reservoir Description of Heterogeneous Carbonate Reservoirs." In Canadian International Petroleum Conference. Petroleum Society of Canada, 2001. http://dx.doi.org/10.2118/2001-009.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Zulkifli, Nur Azah, Lisa Claire Chisholm, Amy Mawarni M Yusoff, Nur Khairina Kosnon, Mohd Zubair Mohd Azkah, and Mohd Amri M Diah. "Defining Heterogeneity and Compartmentalisation Predictions of Minor Reservoirs in Fluvial Environments: Geological and Dynamic Context." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21225-ms.

Full text
Abstract:
Abstract Reservoirs in MN Field comprise predominantly fluvial delta deposits. A number of reservoir modeling studies have been performed for major reservoirs, however, there are still challenges to be addressed. After 20 plus years of production, a project for minor reservoirs has been crafted based on the understanding and challenges of major reservoirs. The primary objective of this study was to improve the understanding of the uncertainties impacting the well performance and reservoir connectivity; and to find potential infill opportunities. A 2D conceptual modelling approach was used as a practical way to incorporate the static and dynamic data of logs, core, seismic and pressure data. Taking the lessons learned from the major reservoir performances, this study focused on the fluvial reservoir sedimentology to address and decrease the uncertainties through the different scales of heterogeneity. Consequently, depositional facies maps were developed with the integration of geophysical study and interpretation derived from seismic analysis. These integrated depositional facies maps were then further refined with the well production data and scenarios of multiple compartments from multiple iterations to fit into the conceptual models of this field. Refined paleo depositional maps for these minor reservoirs allowed for a better understanding on reservoir heterogeneities and further improved the geological understanding. This fundamental study can show us a more precise distribution and tendency of the sand and the scales of heterogeneity with different depositional facies. However, capturing and preserving the different levels of heterogeneities and compartmentalization is complex for some thin sand reservoirs which are below seismic resolution and have low correlation of reservoir properties-seismic response. Additionally, multiple compartments were inferred due to pressure difference and multiple contacts within a reservoir. This was further complicated by the uncertainty in log interpretation due to inadequacy of high confidence data (DST/fluid sampling), suppressed resistivity from shaly sands and below log resolution of thin beds. Despite of these issues and challenges, with integration of all the data available and rigorous team discussions; the minor reservoirs depo-facies, static and dynamic compartmentalization were finalized, leading to enhancement of reservoir prediction, communication and quality.
APA, Harvard, Vancouver, ISO, and other styles
3

Al-Alqum, Wael, Parvez Jamil Butt, Mohan Javalagi, Tareq Al-Zahrani, Umer Khan, Abdalla Laota, and Aklesh Jain. "Geosteering in Thin Reservoirs for Maximum Reservoir Contact." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2008. http://dx.doi.org/10.2523/12372-abstract.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Al-Alqum, Wael, Parvez Jamil Butt, Mohan Javalagi, Tareq Al-Zahrani, Umer Khan, Abdalla Laota, and Aklesh Jain. "Geosteering in Thin Reservoirs for Maximum Reservoir Contact." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2008. http://dx.doi.org/10.2523/iptc-12372-abstract.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Hadiyanto, Imam Fikri, Dina Hanifah, and Wildan Nur Hamzah. "Distribution of Volcanic Rocks Porosity of Dissected Kromong Paleovolcano: Analogue of Volcanic Reservoir." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21240-ms.

Full text
Abstract:
Abstract The potentiality of unconventional play on the volcanic reservoir was evaluated for the purpose to deliver an integrated evaluation of shallow reservoir target associated with the Northwest Java Basin (NWJB). This study provides basis discovery for further exploration and dissemination of volcanic reservoir by presenting an overview of geometric and porosity type analysis of Kromong paleo-volcano complex deposits associated with the NWJB comprehensively. Furthermore, reservoir lithofacies and pore space deployment of Kromong volcanic deposits were studied. The detailed lithofacies analysis was carried out based on field observations from several dissected- and obscure dipping-outcrops in Kromong area associated with NWJB. Following this, a set of outcrop samples were processed for megascopic description integrated with thin-section analysis by using the polarized light microscope and XRF, respectively to assess different types of reservoir pore spaces and structure. Subsequently, the physical properties-porosity measurement was conducted using ImageJ software tools to understand the potentiality of high-quality reservoir formation. The results of this study show that rocks in Kromong area associated with NWJB can be comprehensively classified into reefal limestone for carbonate deposit and into 4 categories, including volcaniclastic lava, sheeting joint lava, pyroclastic breccia, volcanic intrusion, for volcanic deposits. The proposed volcanic reservoirs of volcanic play in this study are lithologically composed of autobreccia lava, sheeting joint lava, pyroclastic breccia to andesitic- and andescitic-dikes, which comprises explosive facies and intrusive facies. Pyroclastic breccia reservoirs are primary pore-type reservoirs with devitrified micropores as main reservoir space. Whilst volcanic dikes reservoirs are mainly porous-fractured-type reservoirs with cooling fracture porosity. In conclusion, following factors that control the presence of a volcanic reservoir are lithology, lithofacies, tectonism and vulcanism. Despite worldwide discoveries of volcanic reservoirs, neither the detailed potentiality evaluation nor the postulated assumption of volcanic reservoir development in NWJB field has been examined sufficiently. This contribution offers knowledge benefits by discussing the potentiality of the Cenozoic-Quarternary volcanic reservoir of the NWJB field and providing a reference for future exploration in the petroleum industry.
APA, Harvard, Vancouver, ISO, and other styles
6

Reeves, Scott, and Larry Pekot. "Advanced Reservoir Modeling In Desorption-Controlled Reservoirs." In SPE Rocky Mountain Petroleum Technology Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/71090-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Ramli, Asari, Ayham Ashqar, and M. Azan Karim. "An Innovative Approach to Integrated Fluid Typing in Depleted Reservoirs." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21215-ms.

Full text
Abstract:
Abstract The economic value of completing a reservoir is strongly influenced by the fluid type. Wells drilled in developed brown field penetrate reservoirs with significant pressure loss due to offset production. A major challenge in evaluating mature reservoirs is the uncertainty introduced by pore fluids with unknown or varying petrophysical properties, such as change hydrocarbon gravity, diminishing pore pressures, and low to absent gas level indication. These are prone to error and uncertainty. Accurate understanding of reservoir fluid properties is therefore a key requirement for successful reservoir management. This manuscript illustrates a successful integrated workflow to ascertain. An integration between LWD triple combo data, near/far neutron, mud logs, pressure measurement, and production history of neighbouring wells, are critical to confirm fluid type within the drilled reservoirs. Cross plots, ratios and confidence analysis are required to ascertain the confidence level. Acquired data was ranked according to uncertainty associated with the acquisition technique, rate of penetration, lag time, mud type, and pre-test drawdown. Mobility was used as an indicator of fluid type or phase change in absence of any major rock type changes. Gas data were verified for any mud contamination and analysed using ratios to verify Hydrocarbon wetness. Data was ranked based on confidence factor determined through data precision and reservoir propertied. We also highlight the uncertainty in measurements. The fluid typing workflow used successfully identified the correct fluid typing, and reduced the reliance on single conventional method, or the need to run pre-test measurements. Data in intervals dominated with residual oil saturation showed misleading fluid type, same applies in high permeability sand, corrected gas data analysis gave a good indication of fluid type and mapped the change in fluid phase when combined with log data, while near/ far neutron aided to correlate the different sands, however due to its relationship with porosity, there is no one correlation could be derived. This paper illustrates that standard petrophysical techniques, such as analysis of density and neutron porosity logs, near/far neutrons, pretest can give misleading results if used in solo without consideration to the uncertainty associated with the measurement. The integration of fundamentally different data has resulted in identifying the fluid typing and its distribution in the reservoir and without integrating other measurements. A fluid typing systematic was developed to ensure the best and cost-effective model to assure the correct fluid type is identified. In this paper, a methodology is proposed which uses the geodesic transform, and integrate various source fundamentally different data, which is routinely acquired, then develop a systematic reasoning of confidence on data precision and accuracy. The system followed ensured the correct mapping of fluid typing in various reservoirs with different petrophysical properties. It is the first time such workflow is followed, and an integrated approach is consistently used in different sandstone reservoirs.
APA, Harvard, Vancouver, ISO, and other styles
8

Cipolla, Craig L., Elyezer Lolon, and Michael J. Mayerhofer. "Reservoir Modeling and Production Evaluation in Shale-Gas Reservoirs." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2009. http://dx.doi.org/10.2523/iptc-13185-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Chen, Yefei, Kongchou Li, Jun Ni, and Qingying Hou. "Four-Dimensional Geological Modeling of Stress-Sensitive Reservoirs of Abnormally High-Pressure Carbonates." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21443-ms.

Full text
Abstract:
Abstract The abnormally high-pressure carbonate dual-medium reservoir of the Kenkiyak Pre-salt oilfield in the littoral Caspian Basin has strong stress sensitivity. With the development of the oil field, the formation pressure drops and the fractures gradually close, resulting in a decrease of the effective permeability of the dual-media reservoir over time. So it is necessary to establish three-dimensional geological models of the dual-medium reservoirs at different times, which is the 4-D geological model. Firstly, the reservoir matrix and fracture permeability model under the original conditions is established by using the dual-medium three-dimensional geological modeling method; Secondly, the formation pressure model for a given period is established by taking the measured well-point formation pressure in a certain period as hard data and combining with the formation pressure change trend in different zones; Thirdly, the carbonate reservoir types are identified by borehole imaging and conventional logging, and the geological model of the reservoir types in the original state is established. Finally, using the relationship between confining pressure and permeability reduction rate of different types of reservoirs obtained by core stress sensitivity experiments, and based on the original matrix and fracture permeability models, the matrix and fracture permeability models of different types of reservoirs at a given period are obtained. Using the method proposed in this paper, the original matrix and fracture permeability model can be corrected to the matrix and fracture permeability model after the formation pressure drops at a certain period, and the 3D geological model of carbonate reservoir in any given periods can be obtained. Newly drilled wells at present confirmed that the geological model established by this method is reasonable and reliable. Taking the data of new wells completed during this period as hard data and the above three-dimensional geological model as soft data, an updated dual-medium model is established, which is more in line with geological reality. Based on the updated geological model, the deployment of oilfield adjustment schemes and well location optimization studies are carried out. The match between the new drilling data and the prediction results reached more than 90%. The method solves the problem of updating the 3D geological model caused by the permeability change of the stress-sensitive reservoir, ensures that the geological model truly reflects the underground geological characteristics, and can be widely applied to the 3D geological modeling of stress-sensitive reservoirs.
APA, Harvard, Vancouver, ISO, and other styles
10

Larsen, J., and N. Bech. "Parallel Simulation of Petroleum Reservoirs." In ECMOR II - 2nd European Conference on the Mathematics of Oil Recovery. European Association of Geoscientists & Engineers, 1990. http://dx.doi.org/10.3997/2214-4609.201411111.

Full text
APA, Harvard, Vancouver, ISO, and other styles

Reports on the topic "Petroleum reservoirs"

1

Abbas Firoozabadi. FRACTURED PETROLEUM RESERVOIRS. Office of Scientific and Technical Information (OSTI), June 1999. http://dx.doi.org/10.2172/825891.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Firoozabadi, A., E. Chang, and G. Q. Tang. Fractured petroleum reservoirs. Office of Scientific and Technical Information (OSTI), January 2000. http://dx.doi.org/10.2172/750060.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Firoozabadi, Dr Abbas. Fractured Petroleum Reservoirs. Office of Scientific and Technical Information (OSTI), January 2000. http://dx.doi.org/10.2172/750251.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Abbas Firoozabadi. RESEARCH PROGRAM ON FRACTURED PETROLEUM RESERVOIRS. Office of Scientific and Technical Information (OSTI), April 2002. http://dx.doi.org/10.2172/834357.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Wilt, M., C. Schenkel, T. Daley, J. Peterson, E. Majer, A. S. Murer, R. M. Johnston, and L. Klonsky. Mapping steam and water flow in petroleum reservoirs. Office of Scientific and Technical Information (OSTI), November 1996. http://dx.doi.org/10.2172/491852.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Willhite, G. P., D. W. Green, J. L. Thiele, C. S. McCool, and K. B. Mertes. Gelled polymer systems for permeability modification in petroleum reservoirs. Office of Scientific and Technical Information (OSTI), September 1991. http://dx.doi.org/10.2172/5118109.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Firoozabadi, A. Research program on fractured petroleum reservoirs. [Quarterly report], October 1--December 31, 1995. Office of Scientific and Technical Information (OSTI), January 1996. http://dx.doi.org/10.2172/207426.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Firoozabadi, A. Research program on fractured petroleum reservoirs. Second quarterly, April 1--June 30, 1995. Office of Scientific and Technical Information (OSTI), July 1995. http://dx.doi.org/10.2172/97330.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Firoozabadi, A. Research program on fractured petroleum reservoirs. Quarterly report, January 1--March 31, 1994. Office of Scientific and Technical Information (OSTI), April 1994. http://dx.doi.org/10.2172/10160964.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

Honarpour, M. M., R. A. Schatzinger, M. J. Szpakiewicz, S. R. Jackson, B. Sharma, L. Tomutsa, and M. M. Chang. Integrated methodology for constructing a quantified hydrodynamic model for application to clastic petroleum reservoirs. Office of Scientific and Technical Information (OSTI), January 1990. http://dx.doi.org/10.2172/5087647.

Full text
APA, Harvard, Vancouver, ISO, and other styles
You might also be interested in the extended bibliographies on the topic 'Petroleum reservoirs' for particular source types:
Journal articles Dissertations / Theses Books
We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!

To the bibliography