Study on enhanced oil recovery by co2 microbubbles injection

STUDY ON ENHANCED OIL RECOVERY BY CO2 MICROBUBBLES INJECTION Le Nguyen Hai Nam September 2022 STUDY ON ENHANCED OIL RECOVERY BY CO2 MICROBUBBLES INJECTION A dissertation submitted to the Department of Earth Resources Engineering, Graduate School of Engineering, Kyushu University, Japan in partial fulfillment of the requirements for the degree of Doctor of Philosophy in Earth Resources Engineering by Le Nguyen Hai Nam September 2022 ABSTRACT Injecting carbon dioxide (CO2) to enhance oil recovery (EOR) during the tertiary stage is expected to be a reasonable and sustainable method to dismiss greenhouse gas emissions However, in many current CO2-EOR projects, their performance is not always achievable due to several drawbacks, such as density effect, gas channeling, and poor sweep efficiency in heterogeneous porous media All those challenges limit the effectiveness of CO2-EOR and raise the additional cost Therefore, it is supposed that using CO2 microbubbles would potentially overcome the challenges in the heterogeneous reservoir and promote a practical approach to achieving both oil improvement and CO2 sequestration goals Microbubbles – Colloidal Gas Aphrons (CGAs) have been reported as unique bubbles with micro-size (10-100 m) consisting of a multilayer shell of surfactant molecules and a spherical gaseous core The previous studies reported the significant stability of microbubbles in comparison with conventional foam and their flow restriction ability However, there have been few sufficient studies on the characteristic of CO2 microbubble and their selective plugging performance to improve oil recovery in the heterogeneous reservoir In this thesis, CO2 microbubbles injection is proposed and examined with designed laboratory experiments Experimental study thoroughly includes CO2 microbubbles system generation, characteristics determination, and flow behavior in porous media from homogeneous sandpack and heterogeneous sandpack models In addition, various features, consisting of CO2 microbubbles fluid characteristics, formation permeability, and operation conditions, were experimentally evaluated for their influences on flow performance in the simulated reservoir Based on the findings from flow experiments in porous media, the oil recovery flooding scheme using CO2 microbubbles has been proposed and successfully performed in sandpack models In conclusion, CO2 microbubbles injection is a promising method to overcome permeability differential issues in heterogeneous reservoirs, thereby enhancing CO2-EOR operation efficiency This thesis consists of five chapters i Chapter reviews the fundamental of the oil recovery process from literature The overview of CO2-EOR was discussed with the associated challenges Therein also highlighted the importance of microbubbles used in petroleum engineering The research problem statement and objectives were presented in that regard Chapter introduces the experimental process with an overview of measurement methods and analysis It evaluated the effects of varying the concentrations of a xanthan gum (XG) polymer, a surfactant (sodium dodecyl sulfate: SDS), and sodium chloride (NaCl) on both the stability and bubble size distribution (BSD) of CO2 microbubbles CO2 microbubble dispersions were prepared using a high-speed homogenizer in conjunction with the diffusion of gaseous CO2 through aqueous solutions The stability of each dispersion was ascertained using a drainage test, while the BSD was determined by optical microscopy and fitted to either normal, log-normal or Weibull functions The results showed that a Weibull distribution gave the most accurate fit for all experimental data Increases in either the SDS or XG polymer concentration were found to decrease the microbubble size However, these same changes increased the microbubble stability as a consequence of structural enhancement Stability was also reduced as the NaCl concentration was increased because of the gravitational effect and coalescence Chapter investigates the plugging performance of CO2 microbubbles in both homogeneous and heterogeneous porous media through a series of sandpack experiments First of all, CO2 microbubble fluids were generated by stirring CO2 gas diffused into polymer (Xanthan gum (XG)) and surfactant (Sodium dodecyl sulfate (SDS)) solution with different gas: liquid ratios Then, CO2 microbubbles fluids were injected into single-core and dualcore sandpack systems The results show that the rheological behaviors of CO2 microbubble fluids in this study followed the Power-law model at room temperature The apparent viscosity of CO2 microbubble fluid increased as the gas: liquid ratio increased CO2 microbubbles could block pore throat due to the “Jamin effect” and increase the resistance in porous media The blocking ability of CO2 microbubbles reached an optimal value at the gas:liquid ratio of 20 % in the homogeneous porous media Moreover, the selective pugging ability of CO2 microbubbles in dual-core sandpack tests was significant CO2 microbubbles ii exhibited a good flow control performance in the high permeability region and flexibility to flow over the pore constrictions in the low permeability region, leading to an ultimate fractional flow proportion (50%:50%) in the dual-core sandpack model with a permeability differential of 1.0:2.0 darcy The fractional flow ratio was considerable compared with a polymer injection At the higher heterogeneity of porous media (0.5:2.0 darcy), CO2 microbubble fluid could still establish a good swept performance This makes CO2 microbubble fluid injection a promising candidate for heterogeneous reservoirs where conventional CO2 flooding processes have limited ability Chapter evaluates the performance of CO2 microbubbles on oil recovery from the single sandpack and parallel sandpack flooding tests All flooding tests were conducted at 45oC The flooding scheme consisted of the injection of brine water (20000 mg/L NaCl concentration) followed by the CO2 microbubble injection In the single sandpack flooding test, about 61.4 % of the original oil in place (OOIP) was recovered after pore volume (PV) of water flooding Then 0.5 PV of CO2 microbubble was injected, which caused a blockage in pore spaces The oil recovery was improved by 23.6% by the chase water flooding at the following stage In the heterogeneous sandpack model with the low/high permeability ratio of 1:4, the CO2 microbubble could adjust to fractional flows in the heterogeneous reservoir and displace the remaining oil in the low permeability region As a result, the injection of CO2 microbubbles improved the total oil recovery up to 86.9% compared to the injection of base solution with 75.28% in total When the low/high permeability ratio of the parallel sandpack is reduced to 1:2, injecting CO2 microbubbles enhanced the oil recovery to 93.28 % in total The displacement efficiency increases with the decrease of sandpack heterogeneity The results suggest that CO2 microbubble is favorable to enhanced oil recovery in heterogeneous reservoirs Chapter concludes the present research by highlighting the major findings and further research suggestions iii TABLE OF CONTENTS ABSTRACT I TABLE OF CONTENTS IV LIST OF FIGURES VII LIST OF TABLES XII ACKNOWLEDGEMENTS XIII CHAPTER INTRODUCTION 1.1 Research Overview 1.1.1 Enhanced Oil Recovery Using Carbon Dioxide (CO2-EOR) 1.1.2 CO2 microbubbles – Colloidal gas aphrons 1.2 Research Objectives 10 1.3 Thesis Outline 10 CHAPTER EXPERIMENTAL DESIGN AND CHARACTERIZATION OF CO2 MICROBUBBLES 12 2.1 Introduction 12 2.2 Materials 13 2.3 Experimental methods 13 2.4 2.3.1 Preparation of base solutions 13 2.3.2 Preparation of CO2 microbubble fluids 14 2.3.3 CO2 microbubble stability assessments 16 2.3.4 Determination of CO2 microbubble size 17 Results and Discussions 21 iv 2.5 2.4.1 Visualization of CO2 microbubbles 21 2.4.2 Stability trials 22 2.4.3 CO2 microbubble size distribution 27 2.4.4 Factors affecting the BSD of CO2 microbubbles 31 Summary 39 CHAPTER FLOW PERFORMANCE OF CO2 MICROBUBBLES IN POROUS MEDIA 40 3.1 Introduction 40 3.2 Experimental section 40 3.3 3.4 3.2.1 Materials 40 3.2.2 CO2 microbubble fluids preparation 41 3.2.3 Measurement of rheological property 41 3.2.4 Statistical analysis 43 3.2.5 Preparation of sandpacks 43 3.2.6 CO2 microbubble fluid flow tests 44 Results and Dicussions 46 3.3.1 Characterization of CO2 microbubbles 46 3.3.2 CO2 Microbubble Fluid Flow in Homogeneous Porous Media 52 3.3.3 CO2 Microbubble Fluid Flow in Heterogeneous Porous Media 59 Summary 65 CHAPTER EVALUATION OF ENHANCED OIL RECOVERY PERFORMANCE BY CO2 MICROBUBBLES FLOODING 66 v 4.1 Introduction 66 4.2 Experimental section 67 4.3 4.4 4.2.1 Materials 67 4.2.2 Flooding experiment 68 Results and Discussion 71 4.3.1 Oil recovery in single sandpack 71 4.3.2 Oil recovery in parallel sandpack 74 Summary 81 CHAPTER CONCLUSIONS AND RECOMMENDATION 82 5.1 Major findings of the research 82 5.2 Future possibility 86 REFERENCES 87 vi LIST OF FIGURES Figure 1.1 Long-term world energy consumption with projection to 2050(adapted from U.S Energy Information Administration, October 2021) Figure 1.2 Overview of oil recovery stages Figure 2.1 Schematic diagram of the preparation of CO2 microbubbles: (1) Homogenizer, (2) Polymer and surfactant solution, (3) Porous stone (gas diffuser), (4) Gas flow meter, (5) Pressure regulator, (6) CO2 gas tank 15 Figure 2.2 Apparatus of CO2 microbubbles generation 15 Figure 2.3 Schematic process of drainage test 17 Figure 2.4 Set up for visualization of CO2 microbubbles: (1) Microscope, (2) chargecoupled device (CCD) camera, (3) computer, and (4) glass-slide 18 Figure 2.5 Analyzing procedure of a CO2 microbubbles sample (a) Raw image, (b) 8-bit image enhanced by contrast, (c) Image after thresholding, (d) Bubbles counting and analyzing 19 Figure 2.6 The difference between CO2 microbubbles and conventional foam, introduced in their structure 22 Figure 2.7 Experimental photograph of CO2 microbubbles drainage with SDS ( 3g/L) and XG (0 g/L) 23 Figure 2.8 Effect of SDS concentration on the stability of CO2 microbubbles (with g/L XG) 24 Figure 2.9 Effect of XG concentration on the stability of CO2 microbubbles (with g/L SDS) 25 vii Figure 2.10 Effect of NaCl concentration on the stability of CO2 microbubbles (with g/L SDS and g/L XG) 26 Figure 2.11 Micrographs of CO2 microbubbles: (a) S1 sample, (b) S2 sample, (c) S3 sample, (d) S4 sample, (e) S5 sample, (f) S6 sample, and (g) S7 sample Scale bar: 100 m 27 Figure 2.12 Bubble size distribution (BSD curves predicted by Normal, Log-normal and Weibull model for (a) S1 sample, (b) S2 sample, (c) S3 sample, (d) S4 sample, (e) S5 sample, (f) S6 sample, and (g) S7 sample 29 Figure 2.13 Q-Q plots for (a) S1 sample, (b) S2 sample, (c) S3 sample, (d) S4 sample, (e) S5 sample, (f) S6 sample, and (g) S7 sample 30 Figure 2.14 Influence of SDS concentration (1, 2, g/L) upon bubble size (b) BSD at three SDS concentrations, experimental and fitted results are represented using icons and solid lines, respectively 31 Figure 2.15 Influence of XG concentration (1,3,5 g/L) upon bubble size (b) BSD at three XG concentrations, experimental and fitted results are represented using icons and solid lines, respectively 33 Figure 2.16 (a) Influence of NaCl concentration (0, 10, 20 g/L) upon bubble size (b) BSD at three NaCl concentrations, experimental and fitted results are represented using icons and solid lines, respectively 34 Figure 2.17 Microscopic views of CO2 microbubbles samples, 60 minutes after preparation (a) S1 sample, (b) S2 sample, (c) S3 sample And (d) Bubble size distribution functions 36 viii • A stability analysis of the CO2 microbubble samples revealed that increasing the XG polymer and SDS concentrations slowed liquid drainage from the microbubbles The XG polymer concentration had the strongest effect on stability Although the results indicated that the CO2 microbubbles were most stable at an optimal salinity, the highest NaCl salt concentration gave the least stable sample because of the gravitational effect and coalescence • This work addressed substantial aspects of CO2 microbubbles application in the EOR process, particularly the importance of stability and BSD of the pertinent materials In addition, this study also illustrated the significance of evaluating the goodness-of-fit values for BSD models before assessing the related parameter Such considerations have not been addressed in the previous studies Therefore, the results obtained in this study would be beneficial to assist the development of microbubbles design in oil and gas technology (2) Several sandpack flooding experiments were systematically designed to investigate plugging characteristics of CO2 microbubbles in porous media Although unconsolidated formations were employed in this work, the dual-core sandpack model with different permeability gives an insight into the movement behavior of CO2 microbubbles in heterogeneous porous media The obtained results can be helpful in the upscaling process from the lab scale to the field 83 scale Based on the experimental results, the following conclusions could be drawn: • The CO2 microbubble fluids behave as shear-thinning fluid regardless of  value The rheological behavior of CO2 microbubble fluid is described with the Power-law model due to its sufficient accuracy Furthermore, the apparent viscosity of CO2 microbubble fluids increases as the gas:liquid ratio increases • The gas:liquid ratio significantly affects the plugging ability of CO2 microbubbles in porous media The pressure drops first increased and then decreased with  (range from 10 to 40%), peaking at  = 20% Because of “Jamin effect”, CO2 microbubbles can temporarily block pore constriction and resist flow in porous media Therefore, the permeability of sandpack significantly influences the plugging performance of CO2 microbubbles Besides, the CO2 microbubble fluid injection with a higher flow rate had a higher pressure drop over the sandpack • The dual-core sandpack flow tests indicate that CO2 microbubbles have good properties for diverting flow and improving swept volume in the low permeable region of the heterogeneous formation They can make a temporary plugging zone in the high permeability sandpack, and change the following fluid flow to the sandpack with low permeability Although the sweep efficiency decreases by increasing the permeability differential of the 84 porous media, CO2 microbubbles fluid is a good candidate for enhancing hydrocarbon recovery (3) Homogeneous single sandpack and heterogeneous parallel sandpacks flooding tests were conducted to evaluate fractional flow and oil recovery enhancement of CO2 microbubbles flooding • The CO2 microbubbles showed an excellent ability to deform themselves and plug the pore throat in porous media At the reservoir temperature, in the homogeneous sandpack model, oil recovery efficiency is more than 26.3% of OOIP over the water flooding because of improved microscopic sweep efficiency caused by pore plugging • In the heterogeneous model, CO2 microbubbles flooding could significantly improve the displacement efficiency in a low permeability sandpack compared to base solution flooding with the same permeability ratio The CO2 microbubble could adjust to fractional flows in the heterogeneous reservoir and displace the remaining oil • As a result, the injection of CO2 microbubbles improved the total oil recovery up to 86.9% compared to the injection of base solution with 75.28% in total When the low/high permeability ratio of the parallel sandpack is reduced to 1:2, injecting CO2 microbubbles enhanced the oil recovery to 93.28 % in total The displacement efficiency increases with the decrease of sandpack heterogeneity The results suggest that 85 CO2 microbubble is favorable to enhanced oil recovery in heterogeneous reservoirs 5.2 Future possibility This work also has 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