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Petroleum reservoir

About: Petroleum reservoir is a research topic. Over the lifetime, 5403 publications have been published within this topic receiving 83535 citations. The topic is also known as: petroleum deposit.


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TL;DR: In this article, structural/stratigraphic closures have been found along the downdip termination of the Upper Jurassic/Lower Cretaceous carbonate shelf edge but encountered no significant hydrocarbon shows.
Abstract: Numerous hydrocarbon shows, including a noncommercial gas and gas-condensate accumulation, occur in the Baltimore Canyon Trough within sandstone units deposited in prograding coastal-plain and transitional-marine environments located updip of an Oxfordian/Kimmeridgian carbonate shelf edge. The coastal-plain and transitional-marine facies are overlain by a fine-grained deltaic complex dominated by delta-plain shales which collectively form a regionally extensive top seal unit. This deltaic complex prograded into a back-reef lagoon during aggradation of lower Kimmeridgian through Berriasian shelf-margin carbonates. Wells drilled seaward of the continental shelf edge (>1500 m water depth) tested large structural/stratigraphic closures along the downdip termination of the Upper Jurassic/Lower Cretaceous carbonate shelf edge but encountered no significant hydrocarbon shows. Reservoir rocks in these wells consist of (1) oolite grainstone, which was deposited within a shoal-water complex located at the Aptian shelf edge, and (2) coral-stromatoporoid grainstone and boundstone, which formed an aggraded shelf-margin complex located at the late Kimmeridgian through Berriasian shelf edge. Structural closures having reservoir and top seals are present in both updip and downdip trends. Hydrocarbon shows in wells along the shelf interior trend indicate the presence of mature source beds, at least locally. The absence of hydrocarbon shows in downdip carbonate reservoirs and around the Schlee Dome, however, suggests charge/migration mechanisms within the fetch areas of these objectives have failed. Failure of charge can be due to (1) absence of mature source rocks, (2) absence of migration pathways from source rocks to reservoirs, and/or (3) absence of top seals at the time of hydrocarbon migration. Continued development of play concepts in the Baltimore Canyon Trough, therefore, requires identification and mapping of potential source-rock intervals and construction of hydr carbon expulsion models to time hydrocarbon generation relative to trap formation.

20 citations

Journal ArticleDOI
TL;DR: Based on the analysis of the hydrocarbon geochemical characteristics in the Kuqa petroleum system of the Tarim Basin, the authors discusses the causes and controlling factors of the phase diversities and their differences in geochemical features.
Abstract: Based on the analysis of the hydrocarbon geochemical characteristics in the Kuqa petroleum system of the Tarim Basin, this study discusses the causes and controlling factors of the phase diversities and their differences in geochemical features. According to the characteristics and differences in oil and gas phase, the petroleum system can be divided into five categories: oil reservoir, wet gas reservoir, condensate gas-rich reservoir, condensate gas-poor reservoir and dry gas reservoir. The causes for the diversities in oil and gas phases include diversities of the sources of parent material, maturity of natural gas and the process of hydrocarbon accumulation of different hydrocarbon phases. On the whole, the Jurassic and Triassic terrestrial source rocks are the main sources for the hydrocarbon in the Kuqa Depression. The small differences in parent material may cause diversities in oil and gas amount, but the impact is small. The differences in oil and gas phase are mainly affected by maturity and the accumulation process, which closely relates with each other. Oil and gas at different thermal evolution stage can be captured in different accumulation process.

20 citations

Journal ArticleDOI
TL;DR: Fractured pre-Cambrian basement rocks are the reservoir from which over a million barrels of oil have been produced from sixteen wells in the Orth field, Rice County, Kansas.
Abstract: Fractured pre-Cambrian basement rocks are the reservoir from which over a million barrels of oil have been produced from sixteen wells in the Orth field, Rice County, Kansas. Similar fractured quartzite is the reservoir from which oil has been produced in four wells in the Kraft-Prusa field and from one well each in the Beaver, Bloomer, Eveleigh, and Trapp fields, all in Barton County; and from six wells in the Ringwald field, five wells in the Heinz field, and two wells in the Silica field, all in Rice County. Fresh pink biotite granite is the reservoir rock producing oil in three wells in the Hall-Gurney field and in one well in the Gorham field, both in Russel County. A few other wells, not investigated by the writer, are reported to be producing from pre-Cambrian rock . All wells known to be producing from pre-Cambrian quartzites are on the summits of buried pre-Cambrian hills. Porosity consists of a reticulated fracture system. The pre-Cambrian reservoir rocks are unconformable overlapped by Pennsylvanian limestones draped above the hills in gentle anticlinal folds which trap oil in multiple thin porous zones in the Topeka (Virgil) and Lansing-Kansas City (Missouri) limestones. Oil migrated locally into the fractures in the pre-Cambrian rocks from the overlying Pennsylvanian rocks or from the truncated Cambro-Ordovician Arbuckle dolomites, themselves an oil reservoir, which are on the flanks of each hill. It is the writer's opinion that the basement rocks have been inadequately tested in the past. Where encountered structurally (or topographically) high, the fractured pre-Cambrian basement rocks are worthy of careful consideration as a potential commercial oil reservoir.

20 citations

Journal ArticleDOI
TL;DR: In this paper, an analysis based on X-ray diffraction instrument shows that most dolomicrite includes clastic particles and argillaceous components because of the combined sedimentation of clastic materials brought from the peripheral fan delta deposit.
Abstract: Qaidam is a plateau saline lacustrine basin in China. The Eocene in western Qaidam mainly consists of lacustrine carbonate, and the sedimentary rocks mainly include micrite, bioclastic limestone, algal limestone, dolomicrite, algal dolomite and so on. Among these rocks, dolomite is the most important petroleum reservoir rock, which mainly includes algal dolomite and dolomicrite. The pores of carbonate are mainly the intercrystalline pores, and there are dissolution pores locally. The analysis based on electronic probe energy spectrum scanning instrument shows that the enrichment region of element Mg in the algal dolomite is highly consistent with the distribution of algal laminas, which means the algal dolomite is a biogenic primary dolomite, because the microbial activities can overcome the kinetic obstacles and create a favorable microenvironment for the formation of dolomite. The analysis based on X-ray diffraction instrument shows that most dolomicrite includes clastic particles and argillaceous components because of the combined sedimentation of clastic materials brought from the peripheral fan delta deposit. The rock composition analysis based on the electronic probe shows that the average content of FeO in the dolomicrite is 0.942 %, and that of MnO is 0.052 %, which are obviously lower than the average contents of Fe and Mn in the hydrothermal dolomite. Meanwhile, due to the high contents of SiO2 and Al2O3, it is considered that the dolomicrite has a penecontemporaneous metasomatic formation mechanism. This type of dolomicrite generated a lot of disseminated intercrystalline pores during the metasomatism. The pore radius is small and the pore number is enormous, which are the main cause of relatively high porosity and relatively low permeability. The type of dolomicrite is a good petroleum reservoir in the study area, so adequate attention shall be given to the dolomicrite during the oil and gas exploration in the carbonate rock reservoir of Eocene in Qaidam Basin.

20 citations

Journal ArticleDOI
TL;DR: Weydt et al. as discussed by the authors developed a new workflow to overcome the gap of knowledge of the reservoir properties, which is used for the interpretation of geophysical data and the parameterization of numerical models and thus are the basis for economic reservoir assessment.
Abstract: . Petrophysical and mechanical rock properties are key parameters for the characterization of the deep subsurface in different disciplines such as geothermal heat extraction, petroleum reservoir engineering or mining. They are commonly used for the interpretation of geophysical data and the parameterization of numerical models and thus are the basis for economic reservoir assessment. However, detailed information regarding petrophysical and mechanical rock properties for each relevant target horizon is often scarce, inconsistent or distributed over multiple publications. Therefore, subsurface models are often populated with generalized or assumed values resulting in high uncertainties. Furthermore, diagenetic, metamorphic and hydrothermal processes significantly affect the physiochemical and mechanical properties often leading to high geological variability. A sound understanding of the controlling factors is needed to identify statistical and causal relationships between the properties as a basis for a profound reservoir assessment and modeling. Within the scope of the GEMex project (EU H2020, grant agreement no. 727550), which aims to develop new transferable exploration and exploitation approaches for enhanced and super-hot unconventional geothermal systems, a new workflow was applied to overcome the gap of knowledge of the reservoir properties. Two caldera complexes located in the northeastern Trans-Mexican Volcanic Belt – the Acoculco and Los Humeros caldera – were selected as demonstration sites. The workflow starts with outcrop analog and reservoir core sample studies in order to define and characterize the properties of all key units from the basement to the cap rock as well as their mineralogy and geochemistry. This allows the identification of geological heterogeneities on different scales (outcrop analysis, representative rock samples, thin sections and chemical analysis) enabling a profound reservoir property prediction. More than 300 rock samples were taken from representative outcrops inside the Los Humeros and Acoculco calderas and the surrounding areas and from exhumed “fossil systems” in Las Minas and Zacatlan. Additionally, 66 core samples from 16 wells of the Los Humeros geothermal field and 8 core samples from well EAC1 of the Acoculco geothermal field were collected. Samples were analyzed for particle and bulk density, porosity, permeability, thermal conductivity, thermal diffusivity, and heat capacity, as well as ultrasonic wave velocities, magnetic susceptibility and electric resistivity. Afterwards, destructive rock mechanical tests (point load tests, uniaxial and triaxial tests) were conducted to determine tensile strength, uniaxial compressive strength, Young's modulus, Poisson's ratio, the bulk modulus, the shear modulus, fracture toughness, cohesion and the friction angle. In addition, X-ray diffraction (XRD) and X-ray fluorescence (XRF) analyses were performed on 137 samples to provide information about the mineral assemblage, bulk geochemistry and the intensity of hydrothermal alteration. An extensive rock property database was created (Weydt et al., 2020; https://doi.org/10.25534/tudatalib-201.10 ), comprising 34 parameters determined on more than 2160 plugs. More than 31 000 data entries were compiled covering volcanic, sedimentary, metamorphic and igneous rocks from different ages (Jurassic to Holocene), thus facilitating a wide field of applications regarding resource assessment, modeling and statistical analyses.

20 citations


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Performance
Metrics
No. of papers in the topic in previous years
YearPapers
202336
202280
2021172
2020179
2019242
2018212