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The AAPG/Datapages Combined Publications Database
AAPG Special Volumes
Abstract
10. Application of Compositional Basin Modeling to GOR and API Prediction in the North Sea
J. Wendebourg,1 S.J. Dppenbecker2
1Institut Franais du P
trole, Rueil-Malmaison, France
2BP, Houston TX, U.S.A.
ACKNOWLEDGMENTS
We thank our colleagues M. Vandenbroucke and J.-L. Rudkiewicz of IFP and A. Pepper T. Dodd and J. Bunney of BP for their valuable discussions. We also thank S. Wolf of IFP and W. Choueiri of Beicip for implementation of the first versions of compositional Temispack. We thank B. Horsfield and P. Kaufman for their constructive reviews and BP for permission to publish the data.
ABSTRACT
The application of basin modeling is commonly aimed at constraining prospect risk of source rock effectiveness and charge presence. The simulation of compositional petroleum generation and multiphase fluid migration
of miscible and compressible fluids adds the ability to predict petroleum value, i.e., fluid phase and properties, in undrilled traps. This functionality was implemented in Institut Fran
ais du P
trole's (IFP) 2-D Temispack program and applied successfully in a
case
study that was aimed at reconstructing gas-oil ratio (GOR) and liquid petroleum density at surface conditions (API) for two North Sea fields, the low-GOR Ninian oil field and the high-GOR Huldra condensate field.
In both fields, the Upper Jurassic Kimmeridge and Heather Formations do overlay the middle Jurassic Brent reservoir/carrier beds and contain source rock intervals with kerogen of Type II (IFP classification) or of class B (BP classification). The modeling study links the low-GOR Ninian oil to the petroleum composition migrating from the half graben west of the field where secondary cracking is not significant. The petroleum fluid at Huldra, a condensate, is derived from a local deep kitchen to the east where all source rocks are mature and secondary cracking is providing the high gas fraction of the trapped petroleum. In both fields, the GOR is closely linked to the cracking reactions of heavy components (nitrogen, sulfur, oxygen organic compounds [NSO], C14+ aromatics) and late gas generation from kerogen cracking. The molecular weight of the C14+ components determines the API. Most importantly, the pressure-volume-temperature (PVT) behavior of the fluids during migration
indicates that a single-phase petroleum flow is by far the dominating process. A significant three-phase
migration
may occur only at depths less than about 3 km.
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