	Property	Symbols	Value	Unit	Comment
	Summary Date	16.03.2004
Geology
	Deposit structure	Anticline
	Rock type	Carbonate Rock			mostly packstone
	Geological period	Cretaceous
	Depositional environment	Deltaic / Tidal
Depths
	Surface Elevation	Z_alt	125	m (above sea)
	Average Formation Top	Z_top	1,457	m TVDSS
	Gas-Oil Contact	GOC	1,460	m TVDSS
	Oil-Water Contact	OWC	1,475	m TVDSS
	Datum	Z_dat	1,475	m TVDSS	= OWC
Thicknesses
	Average formation thickness	H	30	m
	Net-To-Gross Thickness	NTG	0.56
	Oil column thickness	h_o	15	m	field average
	Gas column thickness	h_g	2	m	field average
	Water column thickness	h_w	0	m	field average
Areas
	Net Oil Pay Area	A_O	20	10⁶ m²
	Net Gas Pay Area	A_G	3	10⁶ m²
Volumes
	Total pore volume	V_Φ	> 300	10⁶ m³
	Oil pore volume	V_ΦO	180	10⁶ m³
	Gas pore volume	V_ΦG	20	10⁶ m³
	Aquifer volume	V_aqf	> 100	10⁶ m³
Pressure & Temperature
	Initial reservoir pressure	P_i	14,300	kPa	@ Datum
	Initial reservoir temperature	T_i	67	°C	@ Datum
Porosity and Shaliness
	Effective formation porosity	ϕ_e	25	p.u. (%)	median average
	Shaliness	V_sh	4	%
Compressibility
	Pore compressibility	c_r	1.0	GPa^-1
	Total compressibility in oil area	c_to	2.1	GPa^-1
	Total compressibility in gas area	c_tg	71	GPa^-1
	Total compressibility in aquifer	c_tw	1.45	GPa^-1
Permeability
	Absolute permeability	k_a	150	md	median average
	Vertical-to-horizontal perm ratio	k_v/k_h	0.1
	Oil relative permeability	k_ro	0.8
	Gas relative permeability	k_rg	0.9
	Water relative permeability	k_rw	0.3
Mobility
	Relative oil mobility	M_ro	0.2	cp^-1	k_ro/μ_oat maximum
	Relative gas mobility	M_rg	58	cp^-1	k_rg/μ_g at maximum
	Relative water mobility	M_rw	0.6	cp^-1	k_rw/μ_w at maximum
Saturation
	initial water saturation	s_wi	0.21
	Residual oil saturation to water	s_orw	0.15
	Residual oil saturation to gas	s_org	0.05
	Residual gas saturation to water sweep	s_grw	0.2
Displacement
	Water→Oil Displacement Efficiency	ED_ow	0.81
	Gas→Oil Displacement Efficiency	ED_og	0.94

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