Property | Symbols | Value | Unit | Comment |
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Summary Date | 16.03.2004 |
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Deposit structure | Anticline |
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Rock type | Carbonate Rock | mostly packstone |
Geological period | Cretaceous |
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Depositional environment | Deltaic / Tidal |
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Average Formation Top | Ztop | 1,457 | m TVDSS
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Gas-Oil Contact | GOC | 1,460 | m TVDSS |
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Oil-Water Contact | OWC | 1,475 | m TVDSS |
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Datum | Zdat | 1,475 | m TVDSS | = OWC |
Average formation thickness | H | 30 | m |
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Net-To-Gross Thickness | NTG | 0.56 |
|
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Oil column thickness | ho | 15 | m | field average |
Gas column thickness | hg | 2 | m | field average |
Water column thickness | hw | 0 | m | field average |
Oil + Gas pore volume | VΦHC | 200 | 106 m3 |
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Aquifer volume | Vaqf | > 100 | 106 m3 |
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Net Oil Pay Area | AO | 20 | 106 m2 |
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Net Gas Pay Area | AG | 3 | 106 m2 |
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Initial reservoir pressure | Pi | 14,300 | kPa | @ OWC |
Initial reservoir temperature | Ti | 67 | °C | @ OWC
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Effective formation porosity | | 25 | p.u. (%) | median average |
Compressibility |
Pore compressibility | cr | 1.0 | GPa-1 |
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Total compressibility in oil area | cto | 2.1 | GPa-1 |
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Total compressibility in gas area | ctg | 71 | GPa-1 |
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Total compressibility in aquifer | ctw | 1.45 | GPa-1 |
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Permeability |
Absolute permeability | ka | 150 | md | median average |
Vertical-to-horizontal perm ratio | kv/kh | 0.1 | cp-1 |
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Oil relative permeability | kro | 0.8 |
|
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Gas relative permeability | krg | 0.9 |
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Water relative permeability | krw | 0.3 |
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Relative oil mobility | kro/μo | 0.2 | cp-1 | at maximum |
Relative gas mobility | krg/μg | 58 | cp-1 | at maximum |
Relative water mobility | krw/μw | 0.6 | cp-1 | at maximum |
Saturation |
initial water saturation | swi | 0.21 |
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Residual oil saturation to water | sorw | 0.15 |
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Residual oil saturation to gas | sorg | 0.05 |
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Residual gas saturation to water sweep | sgrw | 0.2 |
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Displacement |
Water→Oil displacement efficiency | EDow | 0.81 |
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Gas→Oil Displacement Efficiency | EDog | 0.94 |
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