Download e-book for kindle: Advances in reservoir geology by Michael Ashton, Geological Society of London

By Michael Ashton, Geological Society of London

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Diagenesis must, therefore, account for the differences between wells Q01, Q03, and Q05. ,. 01 0 I I I I 5 10 15 20 25 Core Porosity (Compacted) % Fig. 13. Compacted porosity (laboratory-measured porosity adjusted to reflect stress at reservoir depth) versus logarithm of core permeability cross-plot for damp interdune facies sandstones from wells Q01/02, Q03/08 and Q05/03. Data displayed are from all damp interdune lithofacies and are taken from all reservoir zones. Petrology Petrological study of productive (Q05, Q03, and Q01) and noneconomic (Q02 and Q04) wells shows substantial differences in mineralogy and texture.

Isotopic analyses (8180, 613C) have been carried out on some selected samples. It is also possible, in some cases to relate isotopic compositions reported in previous studies (Irwin & Hurst 1983; Kantorowicz et al. 1987) to samples examined in this study. Relationships b e t w e e n m a c r o - t y p e s , sequence stratigraphy a n d c e m e n t textures The petrographical characteristics for each 'macro-type' are summarized on Table 3. Macro-type L Examples of textures exhibited in this group are shown in Fig.

56 graphy and production logging. Explanation of the highly variable production rates would not have been possible without extensive core control. References BJORLYKKE, K. 1984. Formation of secondary porosity: How important is it? A. C. (eds) Clastic Diagenesis. American Association of Petroleum Geologists Memoir, 37, 277-286. C. C. 1978. K. southern North Sea. Journal of the Geological Society, London, 135, 25-34. B. 1989. Diagenetic quartzarenite and destruction of secondary porosity. An example from the Middle Jurassic Brent sandstone of northwest Europe.

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