Topic
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 the case of the Chapman Deep Atoka field as discussed by the authors, a complex microfacies mosaic of shallow-water bank limestones was used to produce hydrocarbons in the Delaware basin, where the bank facies consist of cyclic alternations of Donezella bioherms, oolite-biograinstone shoals, and low-energy interbank deposits.
Abstract: Hydrocarbon production at Chapman Deep Atoka field is from a complex microfacies mosaic of shallow-water bank limestones deposited along the northern hingeline of the Delaware basin. Reservoir localization is essentially stratigraphic in terms of depositional and diagenetic facies, although regional draping and a system of vertical fractures are significant structural aspects of the field. The bank facies consist of cyclic alternations of Donezella (algal) bioherms, oolite-biograinstone shoals, and low-energy interbank deposits. Laterally equivalent slope and basinal facies include spiculitic and crinoidal argillaceous limestones and shales, with interbedded lenses of fine-grained carbonate and siliciclastic turbidites. Early diagenetic effects include incipient marine ce entation and the formation of secondary porosity, most of which was occluded by calcite cements, internal sediments, and dolomitization. In contrast, reservoir evolution is principally related to diagenesis in the deep subsurface (mesogenetic) environment. Bulk-volume reduction by chemical and physical compaction was counterbalanced by porosity rejuvenation through the selective dissolution of allochems, cements, and stylolite surfaces, and the formation of open-gash fractures and adjoining stylolites. Although this limited pore system is of inherently low permeability, effective communication within and between individual reservoir lenses was enhanced by later fracturing. Although potential reservoir facies can be mapped regionally and burial diagenetic effects can be recognized petrogr phically, exploration for similar reservoirs in the Delaware basin is hindered by our limited knowledge of mesodiagenesis.
30 citations
TL;DR: The Piceance basin is a hydrocarbon-rich province that has natural gas production from reservoirs ranging in age from Late Jurassic to Eocene and large undeveloped resources of natural gas in coal beds and tight sandstone reservoirs of Cretaceous age as mentioned in this paper.
Abstract: The Piceance basin is a hydrocarbon-rich province that has natural gas production from reservoirs ranging in age from Late Jurassic to Eocene and large undeveloped resources of natural gas in coal beds and tight sandstone reservoirs of Cretaceous age. Gases from all producing intervals are of predominantly thermal origin and become isotopically heavier (delta isotope{13}C[1]: -51.3 to -29.1 o/oo) and chemically drier (C[1]/C[1-5]: 0.26 to 1.00) with increasing thermal maturity of reservoirs (R[o]: 0.45 to 2.40%) over a depth range of 1100 to 11,702 ft (335-3567 m). Scatter in trend is attributed to source rock differences and considerable vertical and lateral migration. Based on chemical and isotopic composition, three major types of gases can be distinguished: those generated from mixed type II and III kerogens, those from dispersed type III kerogen, and those from coal. Gases generated from mixed type II and III kerogens are produced from the Upper Jurassic Morrison Formation, the Lower Cretaceous Cedar Mountain Formation, the Upper Cretaceous Dakota Sandstone, the Upper Cretaceous Mancos "B" producing interval, and marginal marine sandstones of the Upper Cretaceous Iles producing interval. These gases are associated with minor amounts of oil and probably were generated from kerogen in the marine Mancos Shale. Gases generated from dispersed type III kerogen are produced from nonmarine sandstones of the Upper Cretaceous Williams Fork producing inter al and from thermally immature reservoirs in the overlying Paleocene and Eocene Fort Union and Wasatch Formations. These nonassociated gases contain large amounts of CO[2] and probably were generated from carbonaceous shales in the Williams Fork producing interval. Their presence in immature Fort Union and Wasatch reservoirs implies considerable vertical migration. The third type of gas is methane rich, is produced by devolatilization of humic coal, and is generally in coal beds of the Cameo-Fairfield zone of the Williams Fork producing interval. These gases are not the major source for adjacent sandstone reservoirs. A fourth, distinct type of isotopically light thermogenic gas occurs in immature reservoirs of the Eocene Green River Formation. This gas is inferred to have migrated from u identified deeper, more mature source rocks.
30 citations
TL;DR: In this article, the authors presented a new model for pressure transient and derivative analysis for multi-porosity reservoirs that have a distribution of matrix block sizes, which is based on measured fracture spacing distributions.
30 citations
TL;DR: In this article, the effect of three Carbon nanodots in high salinity brines with and without surfactant on static wetting and dynamic wettability alteration of carbonate reservoirs was investigated.
30 citations
TL;DR: In this article, the authors studied the Permian Upper Dalan and Kangan formations in the South Pars Gas Field, Persian Gulf Basin and found that porefilling and poikilotopic anhydrite cements had the greatest negative impact on the reservoir quality whereas dolomitization and dissolution of grains and cements played the most positive role.
30 citations