This Pawr was selected for presentation by an SPE Prwram Committee following review of information containad m an abstract submittad by the author(s). Contents of the paper, as presented, have not been retiewed by the =ety of Petroleum Eng,neers and are subject to correction by the author(s). The material, aa presented, does not necessarily reflect anỹ itlon of the Society of Petroleum Engmeera, Its o~cera, w members. Papers presented at SPE meetings are subject 10 pub~cafion mtiew by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for mmmetial Purpmaa without the~tten consent of the *lety of Petroleum Engineers is prohibited. Permission to reproduce In print is restnctad to an abstract of not more than 300 tis; hllustratlons may not be copied. The abslract must contain mnspicuous acknowledgment of Mere and by tiom the papr was presented. Write Librarian, SPE, PO. Sax 833836, Richardson, TX 75083-3836, U. S.A., fax Ot -972-952-9435. AbstractIn fluvially dominated delta plain reservoirs, such as the Wara formation in the Greater Burgan Field, characterizing a reservoir's flow properties accurately is essential in developing a sound reservoir model. This is easier said than done. Typically, lithofacies identified in cores are correlated to multiple log suite characteristics. These are then used to help define simulation flow properties in wells. In Greater Burgan, with over fif~years of production, much of the field development occurred before modem diagnostic logging tools became available. Therefore, direct correlation of core lithologies and corresponding lithofacies description to multilog character is not possible in the majority of wells.Relationships discovered between shale volume (V~H) ranges and effective porosity (~to permeability transforms allowed us to apply unique rock properties to flow units or "facies" de fried by the V~H-porosity ranges. These flow facies eliminated the difficult task of trying to predict changing lithologies and lithofacies in wells with limited log traces and no core.
This Pawr was selected for presentation by an SPE Prwram Committee following review of information containad m an abstract submittad by the author(s). Contents of the paper, as presented, have not been retiewed by the =ety of Petroleum Eng,neers and are subject to correction by the author(s). The material, aa presented, does not necessarily reflect anỹ itlon of the Society of Petroleum Engmeera, Its o~cera, w members. Papers presented at SPE meetings are subject 10 pub~cafion mtiew by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for mmmetial Purpmaa without the~tten consent of the *lety of Petroleum Engineers is prohibited. Permission to reproduce In print is restnctad to an abstract of not more than 300 tis; hllustratlons may not be copied. The abslract must contain mnspicuous acknowledgment of Mere and by tiom the papr was presented. Write Librarian, SPE, PO. Sax 833836, Richardson, TX 75083-3836, U. S.A., fax Ot -972-952-9435. AbstractIn fluvially dominated delta plain reservoirs, such as the Wara formation in the Greater Burgan Field, characterizing a reservoir's flow properties accurately is essential in developing a sound reservoir model. This is easier said than done. Typically, lithofacies identified in cores are correlated to multiple log suite characteristics. These are then used to help define simulation flow properties in wells. In Greater Burgan, with over fif~years of production, much of the field development occurred before modem diagnostic logging tools became available. Therefore, direct correlation of core lithologies and corresponding lithofacies description to multilog character is not possible in the majority of wells.Relationships discovered between shale volume (V~H) ranges and effective porosity (~to permeability transforms allowed us to apply unique rock properties to flow units or "facies" de fried by the V~H-porosity ranges. These flow facies eliminated the difficult task of trying to predict changing lithologies and lithofacies in wells with limited log traces and no core.
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