| Terra Nova Maps and Statistics |
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Maps & Charts| Terra Nova Long Core Displacement Tests | ||
| Displacing Fluid | Residual Oil Saturation (%) |
Recovery Factor (%) |
| 21% C2+ Gas | 16.5 | 77.7 |
| 40% C2+ Gas | 8.6 | 88.7 |
| Water | 26.9 | 63.7 |
Source: Update to the Application, Section 4.2, p. 41
| Terra Nova Oil-in-Place Estimates (millions m3) |
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| Case Category | |||
| Low | Base | High | |
| Initial Development Area | |||
| Graben | 49.64 | 64.05 | 98.98 |
| East Flank | 50.94 | 78.19 | 100.64 |
| Subtotal | 100.58 | 142.24 | 199.62 |
| Potential Development Area | |||
| North Graben | 0.00 | 2.05 | 30.76 |
| Far East | 0.00 | 46.48 | 50.08 |
| Subtotal | 0.00 | 48.53 | 80.84 |
| Total | 100.58 | 190.77 | 280.46 |
Source: after Supplement A to the Application,
Tables 2.1-2, p. 10; 2.1-5, p. 12 and 2.1-8, p. 14
| Terra Nova Oil Reserves (millions m3) |
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| Reserve Category | ||||||
| Proven | Proven + Probable | Proven + Probable + Possible | ||||
| Initial Development Area | Oil Co's1 | Gov't | Oil Co's2 | Gov't | Oil Co's3 | Gov't |
| Graben | 14.44 | 12.40 | 21.12 | 15.00 | 28.68 | 24.80 |
| East Flank | 17.65 | 19.30 | 25.79 | 23.60 | 34.90 | 39.60 |
| Subtotal | 32.09 | 31.70 | 46.91 | 38.60 | 63.58 | 64.40 |
| Potential Development Area | ||||||
| North Graben | 0.00 | 0.00 | 0.68 | 0.00 | 0.92 | 3.50 |
| Far East | 0.00 | 0.00 | 15.34 | 25.80 | 18.37 | 36.30 |
| Subtotal | 0.00 | 0.00 | 16.02 | 25.80 | 19.29 | 39.80 |
| Total Field | 32.09 | 31.70 | 62.93 | 64.40 | 82.87 | 104.10 |
1: after: Supplement A to the Application,Table 2.4-10, p. 38
2: Supplement A to the Application, Table 2.4-5, p. 36
3: Supplement A to the Application, Table 2.5-15, p. 41
| Terra Nova Development Alternatives Comparison of Oil Recovery and Recovery Efficiencies |
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| Total Field | Fault Block | |||||||||
| K-07 | C-09 | I-97 | H-99 | |||||||
| Cum. Oil 106 m3 |
Recovery Factor | Cum. Oil 106 m3 |
Recovery Factor | Cum. Oil 106 m3 |
Recovery Factor | Cum. Oil 106 m3 |
Recovery Factor | Cum. Oil 106 m3 |
Recovery Factor | |
| 1 | 47.44 | 0.315 | 6.92 | 0.472 | 21.02 | 0.359 | 1.50 | 0.238 | 17.99 | 0.253 |
| 2 | 59.28 | 0.393 | 6.29 | 0.429 | 22.37 | 0.382 | 2.00 | 0.318 | 28.59 | 0.402 |
| 3 | 60.46 | 0.401 | 6.46 | 0.441 | 20.20 | 0.345 | 3.02 | 0.480 | 30.79 | 0.433 |
| 4 | 57.90 | 0.384 | 2.15 | 0.147 | 21.90 | 0.374 | 3.03 | 0.481 | 30.79 | 0.433 |
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1 Vertical wells with I-97 and K-07 gas injection requiring 29 wells 2 Horizontal wells with I-97 and K-07 gas injection requiring 25 wells 3 Horizontal wells with C-09 gas injection requiring 26 wells 4 Horizontal wells with water injection only requiring 26 wells |
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Source: J. Katay, Petro-Canada, July 16, 1997, Table 1
 Lithology
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Hibernia Area  |