Optimization of Efficient Development Modes of Offshore Heavy Oil and Development Planning of Potential Reserves in China
Abstract
:1. Introduction
2. Experiment
2.1. Experimental Purpose
2.2. Experiment Apparatus
2.3. Experiment Procedures
2.4. Experimental Results and Discussion
3. Numerical Simulation
3.1. Matching of the Experimental Data
3.1.1. Building the One-Dimensional Numerical Simulation Model
3.1.2. History Matching
3.2. Development Mode Optimization
3.2.1. Single Sand Body Reservoir
3.2.2. Layered Reservoir
3.2.3. Thick Layer of Super Heavy Oil Reservoir
3.3. Sensitivity Analysis
3.4. Establishment of Cumulative Oil Production per Well
4. Economic Evaluation
4.1. Method of Economic Evaluation
4.2. Basic Mode of Evaluation
4.3. Application Boundary Study
5. Discussion and Application
Development Strategy of Proved Reserves
- (1)
- Combined with the reservoir type and main control factor parameters of proved heavy oil reserves, the cumulative oil production per well can be predicted using the chart of cumulative oil production per well in Figure 12.
- (2)
- Combined with the development status and offshore development environment around the proved reserves, we can determine the engineering mode that can be adopted in the sea area where the heavy oil reserve is located.
- (3)
- According to the predicted oil production and the selected engineering mode, the economic production limit under the optimal engineering mode can be inversely deduced by using the economic limit chart in Figure 13. If the economic oil production limit is not higher than the predicted cumulative oil production per well, the oilfield can realize economic development. On the contrary, it is difficult to realize economic development.
6. Conclusions
- (1)
- Based on the laboratory physical simulation experimental method, the potential of superheated steam development in offshore reservoirs was identified. The numerical simulation equations for heavy oil steam injection development were established, and the matching error of the experimental results was under 10%.
- (2)
- From the numerical simulation comparison, superheated steam flooding after superheated steam huff and puff in single sand body reservoir and layered reservoir, and sidetrack after superheated steam huff and puff in extra and super heavy oil reservoirs were identified as the optimum development modes. The main factors influencing cumulative oil production of steam injection development in different reservoir types were screened by the numerical simulation method and grey correlation method, and prediction charts of cumulative oil production per well were established.
- (3)
- According to the discussion of reserve classification, the economic oil production limit charts for a single well of the different engineering models by the offshore economic evaluation method were established. Compared with other engineering modes, further exploitation and mobile heat injection were lower. At the end of the paper, the economic development mode of proved heavy oil reserves was planned. A total of 18 oilfields or blocks can achieve economic development in different modes, with a cumulative developed reserves of 259 million tons and a peak capacity of 2.78 million tons, which provides a decision for the construction of steam injection capacity of the Bohai heavy oil fields.
- (4)
- Under the current development strategy and engineering modes of offshore heavy oil, it is still difficult to achieve economic development for more than half of the heavy oil reserves. In order to reduce the threshold of economic development, offshore heavy oil should improve quality and efficiency in terms of development mode, cost reduction of drilling and production engineering, and optimization of thermal recovery processes.
Author Contributions
Funding
Data Availability Statement
Conflicts of Interest
References
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Oil Sample | Type of Oil Sample | Oil Viscosity at 50 °C, mPa·s | Porosity, % | Permeability, mD | Oil Saturation, % | Initial Pressure, MPa |
---|---|---|---|---|---|---|
JZ23-2 | Common heavy oil | 350 | 29.0 | 668 | 68.1 | 11.1 |
LD21-2 | Common heavy oil | 2980 | 32.1 | 2480 | 68.0 | 15.1 |
LD5-2N | Super heavy oil | 50,154 | 35.0 | 2894 | 75.2 | 12.0 |
Injection Medium | Experimental Method | Residual Oil Saturation, % | Recovery Factor, % |
---|---|---|---|
atmospheric temperature water (25 °C) | Huff and puff for 8 cycles | 33.2 | 21.2 |
hot water (120 °C) | 23.0 | 33.2 | |
saturated hot water (250 °C) | 14.4 | 43.4 | |
saturated steam (250 °C) | 8.4 | 52.6 | |
superheated steam (300 °C) | 6.8 | 58.5 |
Injection Medium | Experimental Method | Residual Oil Saturation, % | Recovery Factor, % |
---|---|---|---|
atmospheric temperature water (25 °C) | Huff and puff for 8 cycles | 39.3 | 18.5 |
hot water (120 °C) | 25.4 | 27.3 | |
saturated hot water (250 °C) | 16.4 | 38.4 | |
saturated steam (250 °C) | 11.5 | 42.0 | |
superheated steam (300 °C) | 7.1 | 51.8 |
Injection Medium | Experimental Method | Residual Oil Saturation, % | Recovery Factor, % |
---|---|---|---|
atmospheric temperature water (25 °C) | Huff and puff for 8 cycles | 57.5 | 3.3 |
hot water (120 °C) | 46.5 | 9.9 | |
saturated hot water (250 °C) | 27.9 | 16.9 | |
saturated steam (250 °C) | 19.9 | 21.5 | |
superheated steam (300 °C) | 13.8 | 29.9 |
Oilfield | JZ23-2 | LD21-2 | LD5-2N |
---|---|---|---|
Grid size (X·Y·Z), m | 20 × 23 × 1 | 15 × 18 × 1 | 20 × 21 × 1 |
Number of grid (X·Y·Z), number | 112 × 253 × 48 | 162 × 42 × 52 | 202 × 139 × 55 |
Designed number of wells, number | 56 | 16 | 28 |
Reservoir types | Layered reservoir | Single sand body reservoir | Thick layer of super heavy oil reservoir |
Well types | Directional well | Horizontal well | Horizontal well |
Reservoir thickness, m | 38 | 20 | 40 |
Depth of burial, m | 998 | 1396 | 897 |
Reserve volume, 104 m3 | 2824 | 1025 | 2801 |
Designed well spacing, m | 200~220 | 180~200 | 125~150 |
Comparison scheme | Superheated steam huff and puff for 16 cycles (1), switching to superheated steam flooding after superheated steam huff and puff for 4 cycles (2), switching to superheated steam flooding after superheated steam huff and puff for 8 cycles (3), sidetracking after superheated steam huff and puff for 8 cycles (4). Corresponding to the coordinate axis in the following figures. |
Reservoir Types | Reference Pressure, MPa | Reservoir Thickness, m | Oil Saturation | Oil Viscosity, mPa·s | Permeability, mD | Water Energy (times) | Net-to-Gross Ratio (NTG) |
---|---|---|---|---|---|---|---|
Single sand body reservoir | 6.5~16.0 | 4~40 | 0.5~0.68 | 350~3000 | 300~5000 | 0.1~7 | |
Layered reservoir | 6.5~16.0 | 10~50 | 0.5~0.68 | 350~5000 | 300~3000 | 0.1~10 | 0.3~0.9 |
Thick layer of extra and super heavy oil reservoir | 6.5~14.0 | 20~60 | 0.5~0.9 | 10,000~50,000 | 2000~5000 | 10~50 |
Reservoir Types | Reservoir Pressure MPa | Reservoir Thickness m | Oil Saturation | Oil Viscosity mPa·s | Permeability mD | Water Energy | NTG | Cumulative Oil Production 10 Thousand Tons |
---|---|---|---|---|---|---|---|---|
Single sand body reservoir | 6.5 | 4 | 0.50 | 350 | 300 | 0.1 | 7.7 | |
8 | 8 | 0.54 | 500 | 1000 | 1.0 | 10.2 | ||
10 | 10 | 0.57 | 750 | 2000 | 2.0 | 12.9 | ||
12 | 20 | 0.61 | 1000 | 3000 | 3.0 | 16.0 | ||
14 | 30 | 0.64 | 2000 | 4000 | 5.0 | 17.2 | ||
16 | 40 | 0.68 | 3000 | 5000 | 7.0 | 19.5 | ||
Layered reservoir | 6.5 | 4 | 0.50 | 350 | 300 | 0.1 | 0.3 | 5.0 |
8 | 8 | 0.54 | 750 | 1000 | 1.0 | 0.5 | 5.2 | |
10 | 10 | 0.57 | 1000 | 1500 | 2.0 | 0.6 | 6.0 | |
12 | 20 | 0.61 | 2000 | 2000 | 3.0 | 0.7 | 10.8 | |
14 | 30 | 0.64 | 3000 | 2500 | 5.0 | 0.8 | 15.2 | |
16 | 40 | 0.68 | 5000 | 3000 | 10.0 | 0.9 | 17.9 | |
Thick layer of extra and super heavy oil reservoir | 6.5 | 20 | 0.50 | 10,000 | 2000 | 10.0 | 7.8 | |
8 | 30 | 0.60 | 20,000 | 3000 | 20.0 | 10.3 | ||
10 | 40 | 0.70 | 30,000 | 4000 | 30.0 | 11.0 | ||
12 | 50 | 0.80 | 40,000 | 5000 | 40.0 | 11.0 | ||
14 | 60 | 0.90 | 50,000 | 6000 | 50.0 | 10.8 |
Reservoir Types | Reservoir Pressure f | Reservoir Thickness f | Oil Saturation f | Oil Viscosity f | Permeability f | Water Energy f | NTG f | Cumulative Oil Production f |
---|---|---|---|---|---|---|---|---|
Single sand body reservoir | 0.59 | 0.21 | 0.85 | 0.28 | 0.12 | 0.03 | 0.57 | |
0.72 | 0.43 | 0.91 | 0.39 | 0.39 | 0.33 | 0.76 | ||
0.90 | 0.54 | 0.97 | 0.59 | 0.78 | 0.66 | 0.96 | ||
1.08 | 1.07 | 1.03 | 0.79 | 1.18 | 0.99 | 1.19 | ||
1.26 | 1.61 | 1.09 | 1.58 | 1.57 | 1.66 | 1.28 | ||
1.44 | 2.14 | 1.15 | 2.37 | 1.96 | 2.32 | 1.24 | ||
Layered reservoir | 0.59 | 0.21 | 0.85 | 0.17 | 0.17 | 0.03 | 0.50 | 0.47 |
0.72 | 0.43 | 0.91 | 0.37 | 0.58 | 0.28 | 0.52 | 0.79 | |
0.90 | 0.54 | 0.97 | 0.50 | 0.87 | 0.57 | 0.60 | 0.95 | |
1.08 | 1.07 | 1.03 | 0.99 | 1.17 | 0.85 | 1.07 | 1.11 | |
1.26 | 1.61 | 1.09 | 1.49 | 1.46 | 1.42 | 1.52 | 1.26 | |
1.44 | 2.14 | 1.15 | 2.48 | 1.75 | 2.84 | 1.79 | 1.42 | |
Thick layer of extra and super heavy oil reservoir | 0.64 | 0.50 | 0.71 | 0.33 | 0.50 | 0.33 | 0.76 | |
0.79 | 0.75 | 0.86 | 0.67 | 0.75 | 0.67 | 1.01 | ||
0.99 | 1.00 | 1.00 | 1.00 | 1.00 | 1.00 | 1.08 | ||
1.19 | 1.25 | 1.14 | 1.33 | 1.25 | 1.33 | 1.08 | ||
1.39 | 1.50 | 1.29 | 1.67 | 1.50 | 1.67 | 1.06 |
Reservoir Types | Reservoir Pressure | Reservoir Thickness | Oil Saturation | Oil Viscosity | Permeability | Water Energy | NTG |
---|---|---|---|---|---|---|---|
Single sand body reservoir | 0.5691 | 0.8491 | 0.7294 | 0.8494 | 0.7572 | 0.7741 | |
Layered reservoir | 0.6062 | 0.8735 | 0.7732 | 0.8503 | 0.6908 | 0.8203 | 0.8730 |
Thick layer of extra and super heavy oil reservoir | 0.6832 | 0.8502 | 0.7897 | 0.7232 | 0.7071 | 0.8323 |
Development Mode | Utilization Reserves (Million Tons) | Standardized Platform | Small Wellhead Platform | Center Processing Platform | Steam Injection Facilities |
---|---|---|---|---|---|
Independent development | >20 | Newly build | Newly build | Newly build | |
10~20 | Newly build | Newly build | Newly build | ||
Relying on development | >20 | Newly build | Newly build | ||
10~20 | Newly build | Newly build | |||
Further development | <10 | Newly build | |||
Mobile heat injection | Dependent on reserve scale and supporting conditions |
Producing Reserves, 10 Thousand Tons | Development Modes | Economic Cumulative Production per Well, 10 Thousand Tons | ||||
---|---|---|---|---|---|---|
Independent Development | Relying on Development | Further Exploitation | Mobile Heat Injection (Without Relying on) | Mobile Heat Injection (Relying on) | ||
800 | Steam flooding after steam huff and puff | 8.1 | 6.5 | |||
2000 | 10.9 | 9.4 | 6.2 | 9.4 | 8.0 | |
4000 | 10.6 | 8.9 | 9.3 | 7.8 | ||
1000 | Sidetracking after steam huff and puff | 9.7 | 7.6 | |||
2000 | 12.7 | 11.2 | 7.8 | 11.0 | 9.7 | |
4000 | 12.5 | 10.5 | 11.2 | 9.8 |
Development Mode | Producing Reserves Million Tons | Number of Oilfield Involved | Oilfield Involved |
---|---|---|---|
Independent development | 82 | 2 | JZ23-2, LD5-2N |
Relying on development | 25 | 1 | KL9-6 |
Further exploitation | 55 | 4 | LD27-2, LD16-3, etc. |
Mobile heat injection | 97 | 11 | PL19-3, QHD33-1S, etc. |
Difficult to realize economic development at present | 383 |
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Wang, T.; Liu, F.; Li, X. Optimization of Efficient Development Modes of Offshore Heavy Oil and Development Planning of Potential Reserves in China. Water 2023, 15, 1897. https://doi.org/10.3390/w15101897
Wang T, Liu F, Li X. Optimization of Efficient Development Modes of Offshore Heavy Oil and Development Planning of Potential Reserves in China. Water. 2023; 15(10):1897. https://doi.org/10.3390/w15101897
Chicago/Turabian StyleWang, Taichao, Fengming Liu, and Xin Li. 2023. "Optimization of Efficient Development Modes of Offshore Heavy Oil and Development Planning of Potential Reserves in China" Water 15, no. 10: 1897. https://doi.org/10.3390/w15101897