About This Item
This article has been peer-reviewed and accepted for publication in a future issue of the AAPG Bulletin. This abstract and associated PDF document are based on the authors' accepted "as is" manuscript.
Editorial Policy for Ahead of Print
Cite This Item
Display Citation
Share This Item
Visit Publisher's Website 
Ahead of Print Abstract
DOI:10.1306/02032624050
Porosity and permeability of Mauddud reservoirs in Raudhatain and Sabiriyah oilfields, Kuwait: interpretation of controlling processes
Stephen N. Ehrenberg, Laura Galluccio, 
Boris
Kostic, Gianluca Frijia, Sabry Abd El-Aziz, Nour Esam Alabboud, and Raja Ramalingam
Ahead of Print Abstract
The middle Cretaceous (Albian) Mauddud Formation is a complexly layered limestone reservoir of around 117 m thickness in the Raudhatain and Sabiriyah fields. Stratigraphic trends in reservoir quality are strongly related to smaller (4th-order) depositional sequences, and there is a large-scale upward-increase in quality through the 3rd-order highstand systems tract which makes up most of the formation. Depositional environments and textures show only subtle correlation with porosity and permeability within the proximal, inner-ramp facies, but the more distal, muddier deposits have distinctly lower reservoir quality. Petrography reveals overall volumetric dominance of micropores over macropores. Karst surfaces are not observed in the studied cores, but meteoric water may well have been important during early diagenesis. Heterogeneity of reservoir quality results in large degree from heavily calcite-cemented nodules and thicker cemented zones, with the heavily cemented masses distinguished from surrounding porous limestone by the absence of oil staining. The nodular cementation was probably localized by burrowing and was partly supplied by early dissolution of locally concentrated aragonitic green algae. Field-wide compilations of core and log data reveal trends of upward porosity increase from the flanks to the crest of each field which are similar to the porosity trends of giant domal oilfields in Abu Dhabi and the North Sea, where late calcite cementation was inhibited by oil accumulation. The maximum crest-flank porosity difference due to late cementation is around ten volume percent. This study was performed to provide input for building reservoir models, but has broader significance for understanding the impact on reservoir quality of depositional environments, cemented nodules, sequence stratigraphy, and the preservation of crestal porosity by oil in many other microporous limestone reservoirs.
Pay-Per-View Purchase Options
The article is available through a document delivery service. Explain these Purchase Options.
|
Watermarked PDF Document: $16 |
Watermarked Document –
A Watermarked Document is branded with the name of the original licensed customer to discourage unauthorized users from sharing the document outside the user's organization. The PDF is no longer restricted to one machine, but can be circulated to others in the same company or department. A Watermarked Document also can be printed for hard copy distribution internally but is not authorized for outside distribution nor posting on the internet. Users will not be able to cut-and-paste text or images from one document to another.
|
| Open PDF Document: $28 |
Open Document –
An Open Document is a fully functional PDF that can be circulated (a digital copy or hard-copy printed documents) outside the purchasing organization. Purchase of an Open Document does NOT constitute license for republication in any form, nor does it allow web posting without prior written permission from AAPG/Datapages
([email protected]).
|
AAPG Member?
Please login with your Member username and password.
Members of AAPG receive access to the full AAPG Bulletin Archives as part of their membership. For more information, contact the AAPG Membership Department at [email protected].
