Optimization of EOR Displacement Methods Based on Multiple Factor Analysis

Table 2

Analytical data of examples.

Evaluation parameters (quantitative scoring)	Typical block A	Typical block B	Typical block C	Target block
Oil displacement mode	Polymer flooding	Burning oil layer and steam flooding	Ternary composite flooding	To be matched
Reservoir type	Assembly and rules to expand the block of the application well network	Assembly and rules to expand the block of the application well network	Assembly and rules to expand the block of the application well network	Assembly and rules to expand the block of the application well network
Rock characteristics	Conglomerate	Conglomerate	Carbonatite	Conglomerate
Reservoir depth (m)	2330	1300	2622	2313
Reservoir pressure (MPa)	Greater than or equal to the minimum miscible pressure	Greater than or equal to the minimum miscible pressure	Greater than or equal to the minimum miscible pressure	Greater than or equal to the minimum miscible pressure
Reservoir temperature (°C)	78	70	82	91
Average effective thickness of single layer (m)	10.2	3.7	9.1	2.8
Net to gross ratio (f)	0.58	0.52	0.64	0.68
Porosity (%)	15	21	23	33
Air permeability (10^-3 μm^2)	325	250	320	135
Oil saturation (%)	58	30	26	27
Permeability variation coefficient (f)	0.53	0.60	0.63	0.57
Bottom water influence	Small	No	No	Small
Side water impact	No	Small	No	Small
Crack/cave	Small	Small	Small	Big
Formation dip	6	18	12	33
Gas source	No	No	No	Air
Upper and lower compartments and tube closure	Basic closure	Completely closed	Basic closure	Completely closed
Single storage coefficient (10^4 t/(km^2·m))	16	18	20	15
Formation crude oil viscosity (MPa·s)	58	900	120	70
Crude oil density (g/cm^3)	0.69	0.50	0.85	0.56
Acid value of crude oil (mgKOH/g)	16.62	28.88	11.15	12.43
Formation water salinity (mg/L)	12212	5132	52312	31872
Divalent ion content (mg/L)	560	23	19	130
Enhanced oil recovery (%)	26.54	35.87	31.22	Treatment test