Research Article
Alkali Effect on Alkali-Surfactant-Polymer (ASP) Flooding Enhanced Oil Recovery Performance: Two Large-Scale Field Tests’ Evidence
Table 1
Comparison of basic reservoir physical properties.
| | Parameters | Whole test area | Central well area | | B-1-D | B-2-X | B-1-D | B-2-X |
| | Area, km2 | 1.92 | 1.21 | 1.13 | 0.79 | | Injectors/producers | 49/63 | 35/44 | 49/36 | 35/24 | | Well density (1/km2) | 58.33 | 65.28 | 75.22 | 74.68 | | Average sandstone thickness (m) | 10.6 | 8.1 | 11.8 | 8.8 | | Average effective thickness (m) | 7.7 | 6.6 | 8.4 | 7.1 | | Average effective permeability(D) | 0.670 | 0.533 | 0.675 | 0.529 | | OOIP (104 ton) | 240.71 | 116.31 | 143.41 | 75.64 | | Pore volume(104 m3) | 505.11 | 219.21 | 298.44 | 142.66 | | Well pattern | Five-spot | Five-spot | Five-spot | Five-spot | | Well spacing (m) | 125 | 125 | 125 | 125 | | Formation water type | NaHCO3 | NaHCO3 | NaHCO3 | NaHCO3 | | Formation brine salinity (mg/L) | 5611 | 6037 | 5611 | 6037 | | Calcium ion (mg/L) | 35.97 | 20–40 | 35.97 | 20–40 | | Magnesium ion (mg/L) | 9.44 | 10–20 | 9.44 | 10–20 | | Target formation | SII1-9 | SII10-12 | SII1-9 | SII10-12 | | Formation depth (m) | 838–870 | 872–883 | 838-870- | 872–883 | | Formation-oil viscosity (cP) | 8.2–9.3 | 8.2–10.4 | 8.2–9.3 | 8.2–10.4 | | Dead oil viscosity (cP) | 17.55 | 16.6 | 17.55 | 16.6 | | Formation temperature (°C) | 42.4 | 43–48 | 42.4 | 43–48 |
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