Laboratory Investigation of Miscible CO2-Induced Enhanced Oil Recovery from the East-Southern Pre-Caspian Region
Abstract
1. Introduction
2. Materials and Methods
2.1. Geological Settings
2.2. Oil and Brine Used in Core Flooding
2.3. Minimum Miscible Pressure Estimation
2.4. Experimental Procedure
- ˗
- Core samples were saturated with model reservoir brine under controlled pressure and temperature conditions, with injection rates and fluid volumes carefully recorded.
- ˗
- Oil was subsequently injected until all brine was displaced, followed by a stabilization period of 24 h to ensure equilibrium.
- ˗
- CO2 was injected at a constant rate, and the produced fluid mixture (oil, water, and CO2) was separated and measured using a dedicated separator.
- ˗
- To assess the impact of CO2 injection, porosity and permeability were measured both before and after the experiment using the same core plug. These measurements were conducted under identical pressure and temperature conditions (13 MPa, 42 °C) using a single core sample, allowing reliable comparison of the property alterations.
- ˗
- SEM and XRD analyses were performed on the post-experiment samples to evaluate mineralogical and structural transformations. These methods provided a comprehensive understanding of the dynamic processes occurring within the reservoir rock during CO2 injection, offering valuable insights into optimizing EOR operations.
- The setup includes multiple high-pressure core holders made from corrosion-resistant stainless steel, ensuring uniform pressure distribution for accurate fluid displacement experiments.
- An integrated network of pipes and valves controls fluid injection and extraction, enabling smooth phase transitions between brine, oil, and gas. High-precision valves ensure leakage-free operation.
- A transparent fluid storage bottle and collection unit facilitate real-time monitoring of displaced fluids. Pressure and flow sensors connected to control units provide continuous feedback for precise experimental control and data acquisition.
- The core holders and fluid management system are mounted on a modular, mobile aluminum frame, enhancing adaptability and integration with other experimental setups. An auxiliary power distribution strip ensures reliable operation, minimizing electrical interference.
- ˗
- CO2 Cylinder: A high-capacity (up to 50 L) CO2 storage unit equipped with a pressure regulator to maintain a stable and controlled gas supply, ensuring consistent injection conditions.
- ˗
- Pressure Regulator: A precision regulator that modulates CO2 flow to maintain the required pressure for experimental stability.
- ˗
- Stabilization Tank: A dedicated buffer unit designed to collect displaced fluids during CO2 injection or regulate fluid flow to prevent system fluctuations.
- ˗
- High-Pressure Tubing: A network of reinforced stainless-steel pipelines and hoses ensuring secure, high-pressure transport of CO2 and fluids between components, minimizing leakage risks and enhancing operational safety.
- ˗
- Monitoring Instruments (Pressure Gauges, Flow Meters): Integrated high-precision monitoring devices calibrated for real-time measurement and regulation of CO2 and fluid flow parameters.
2.5. Core Flooding Experimental Conditions
2.6. Scanning Electron Microscopy (SEM)
2.7. X-Ray Diffraction Analysis (XRD)
3. Results
Core Samples’ Characterization
4. Simulation Study
- ✓
- Baseline reservoir conditions were established through initialization, ensuring accurate starting points for CO2 injection scenarios.
- ✓
- Laboratory measurements were used to calibrate model parameters. This step ensured alignment between simulated outputs and actual reservoir behavior.
- ✓
- Laboratory-derived fluid properties, core analysis, and PVT data were incorporated into the model to reflect realistic reservoir conditions and fluid responses to CO2 injection.
5. Conclusions
Author Contributions
Funding
Data Availability Statement
Conflicts of Interest
References
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Retrieval Depth, Meters | Porosity, % | Permeability, mD | Reservoir Pressure, MPa | Viscosity of Oil, mPa·s | Reservoir Temperature, °C |
---|---|---|---|---|---|
1057.47 | 30.3 | 144.5 | 10.5 | 18.5 | 42 |
Component | NaHCO3 | Na2SO4 | MgCl2·6H2O | CaCl2 | NaCl |
---|---|---|---|---|---|
Content, g/L | 0.289 | 1.065 | 15.475 | 14.898 | 196.953 |
Parameters | Before | After |
---|---|---|
Porosity after the Experiment, % | 30.3 | 22.2 |
Permeability after the Experiment, mD | 144.5 | 116.6 |
Oil Recovery Coefficient (CO2 Flooding), % | - | 54 |
Element | O | Si | Cl | Fe | Na | Al | K | Mg | Total |
---|---|---|---|---|---|---|---|---|---|
Content, % | 44.71 | 16.25 | 12.31 | 8.86 | 7.35 | 5.18 | 4.64 | 0.69 | 100 |
Element | O | Si | Al | K | Total |
---|---|---|---|---|---|
Content, % | 56.8 | 23.2 | 12.6 | 7.5 | 100 |
Parameter | Model |
---|---|
Size | 93 × 88 × 78 |
Total Cells | 638,352 |
Active Cells | 194,413 |
Cell Size, m | 100 × 100 × 1 |
Type | E300 |
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Niyazbayeva, A.B.; Merbayev, R.B.; Samenov, Y.R.; Zholdybayeva, A.T.; Kozhagulova, A.A.; Shabdirova, A.D. Laboratory Investigation of Miscible CO2-Induced Enhanced Oil Recovery from the East-Southern Pre-Caspian Region. Processes 2025, 13, 2566. https://doi.org/10.3390/pr13082566
Niyazbayeva AB, Merbayev RB, Samenov YR, Zholdybayeva AT, Kozhagulova AA, Shabdirova AD. Laboratory Investigation of Miscible CO2-Induced Enhanced Oil Recovery from the East-Southern Pre-Caspian Region. Processes. 2025; 13(8):2566. https://doi.org/10.3390/pr13082566
Chicago/Turabian StyleNiyazbayeva, Ainur B., Rinat B. Merbayev, Yernazar R. Samenov, Assel T. Zholdybayeva, Ashirgul A. Kozhagulova, and Ainash D. Shabdirova. 2025. "Laboratory Investigation of Miscible CO2-Induced Enhanced Oil Recovery from the East-Southern Pre-Caspian Region" Processes 13, no. 8: 2566. https://doi.org/10.3390/pr13082566
APA StyleNiyazbayeva, A. B., Merbayev, R. B., Samenov, Y. R., Zholdybayeva, A. T., Kozhagulova, A. A., & Shabdirova, A. D. (2025). Laboratory Investigation of Miscible CO2-Induced Enhanced Oil Recovery from the East-Southern Pre-Caspian Region. Processes, 13(8), 2566. https://doi.org/10.3390/pr13082566