1. Alkali-Surfactant-Polymer Process
Shunhua Liu
George J. Hirasaki
Clarence A. Miller

2. Outline Surfactant adsorption IFT measurement and ultra-low IFT region
Characteristics of Alkali-Surfactant-Polymer process
Implementation of ASP in dolomite and silica sand pack

5. the contour of maximal adsorption for N57 IOS(4:1)

8. Without Na2CO3

9. Without Na2CO3

10. Conclusions 1
Both alkali concentration and salinity influence the surfactant adsorption significantly. The presence of Na2CO3 can reduce the surfactant adsorption. However, higher salinity increases surfactant adsorption and counteracts the adsorption reduction by alkali.
The concentration domain with low surfactant adsorption for the current surfactant is: [Na2CO3]>0.2% and [NaCl]<3%.
The presence of Na2CO3 reduces the adsorption for N67 and IOS respectively significantly.
The presence of sodium oleate and sodium naphthenates from Fisher Scientific does not reduce the synthetic surfactant adsorption on calcite, in the absence of Na2CO3.

11. Outline Surfactant adsorption IFT measurement and ultra-low IFT region
Characteristics of Alkali-Surfactant-Polymer process
Implementation of ASP in dolomite and silica sand pack

12. What is the oil-rich emulsion?

13. Photos of spinning drop at different time
Photos of spinning drop at different time. 0.2% NI blend / 1% Na2CO3 / 2% NaCl

14. 0.2% NI blend / 1% Na2CO3 / 2% NaCl
Photo of two different spinning drops with different amount of oil-rich emulsion
0.2% NI blend / 1% Na2CO3 / 2% NaCl

15. Comparison of phase appearance of 0
Comparison of phase appearance of 0.2% NI / 1% Na2CO3 / x % NaCl at different settling time

18. IFT of 0.2% NI blend / 1% Na2CO3 / 2% NaCl with different settling time

19. The standard spinning drop IFT procedure
1. Mix the crude oil with the alkaline surfactant solutions
2. Rotate the mixture for 24 hours to reach the equilibrium.
3. After settling the mixture for 4 hours, oleic and aqueous phases were taken out into different syringes.
4. Since these samples in the syringes may continue to settle and the settling time in the syringe may be different, they were shaken before the IFT spinning drop measurement so that they can be considered as the same sample that was obtained after 4 hours settling.
5. Before the spinning drop measurement, the aqueous phase was centrifuged in the spinning tube. Some of the oil-rich emulsion was removed by syringe because the sample will be too dark if too much oil-rich emulsion is left. The remaining oil-rich emulsion should be slightly less volume than the volume of the excess oil drop that is added into the spinning drop tube.
6. Let the oil drop settle in the vertical tube for some time (~12 hours) so that the oil-rich emulsion can equilibrate with the oil and the lower phase microemulsion.
7. Begin the spinning drop IFT measurement.

26. IFT change with salinity for 0.2NI-1%Na2CO3/WOR=3

27. Conclusions 2
In the alkali-surfactant system, the oil-rich emulsion plays an important role in the low IFT.
A spinning drop IFT measurement procedure which can reach the equilibrium IFT quickly for alkali-surfactant system was introduced.
The NI Blend-MY4-Na2CO3 system has a wider low IFT region than normally seen for single surfactant systems.

28. Outline Surfactant adsorption IFT measurement and ultra-low IFT region
Characteristics of Alkali-Surfactant-Polymer process
Implementation of ASP in dolomite and silica sand pack

29. The width of low-tension region
Narrow Low IFT contour (extrapolated from the synthetic surfactant only)
Log10 IFT
Over-optimum
Under-optimum

30. Wide Low IFT contour (extrapolated from experimental data)
Log10 IFT
Over-optimum
Under-optimum

31. Soap /synthetic surfactant ratio =0.35

32. Narrow low IFT region
Wide low IFT region

33. Wide low IFT region
Narrow low IFT region
Recovery=95.0%
Recovery=62.3%

34. Narrow low IFT region
Wide low IFT region

36. 2. The effect of viscosity

37. injecting solution viscosity=24cp injecting solution viscosity=40cp
Mobility Ratio = 0.91
injecting solution viscosity=40cp
Mobility Ratio =0.54

38. injecting solution viscosity=40cp injecting solution viscosity=24cp
Mobility Ratio =0.54
injecting solution viscosity=24cp
Mobility Ratio = 0.91
Recovery=95.0%
Recovery=86.1%

39. injecting solution viscosity=40cp injecting solution viscosity=24cp
Mobility Ratio =0.54
injecting solution viscosity=24cp
Mobility Ratio = 0.91

40. Conclusions 3
The width of the low IFT region is a key factor for recovery. Narrow low IFT region will have less recovery because oil will be trapped again when the IFT increases. When the low IFT region is wide enough, less oil will be trapped after the low tension region.
ASP process is more robust because of its large operational salinity region with wide low IFT region.
The injection solution viscosity has significant effect on recovery. Lower aqueous phase viscosity, i.e., higher mobility ratio, has lower oil recovery even with wide low IFT region. This is because the oil fractional flow increases with the aqueous phase viscosity.

41. Outline Surfactant adsorption IFT measurement and ultra-low IFT region
Characteristics of Alkali-Surfactant-Polymer process
Implementation of ASP in dolomite and silica sand pack

42. Treatment before ASP Dolomite sand pack Water Flooding Oil Flooding
Aged in 60ºC for 60 hours
0.1PV PV PV PV PV 3.0PV

43. Oil Recovery of Water Flooding
Dolomite sand pack

44. ASP Process Injecting solution viscosity: 40 cp
Dolomite sand pack
Injecting solution viscosity: 40 cp
Injecting surfactant concentration:0.2%
Surfactant slug size: 0.5PV
Injecting salinity: 2% NaCl
Injecting alkalinity: 1.0%Na2CO3
Initial oil saturation: 0.18

45. Injecting Pore Volumes
ASP Process
Dolomite sand pack
Injecting Pore Volumes

46. Oil Recovery of ASP
Dolomite sand pack

47. History of pressure drop
Dolomite sand pack
History of pressure drop

48. Effluent of ASP Effluent Pore Volumes Dolomite sand pack

49. Comparison between simulation and experiments
Dolomite sand pack

50. ASP Experiment in 40 darcy Sandpack
Silica sand pack
ASP Experiment in 40 darcy Sandpack
0.5% NI, 2% NaCl

51. History of pressure drop
Silica sand pack
History of pressure drop

52. Comparison between simulation and experiments
Silica sand pack

53. ASP Experiment in 40 darcy Sandpack
Silica sand pack
ASP Experiment in 40 darcy Sandpack
0.5% NI, 4% NaCl

54. History of pressure drop
Silica sand pack
History of pressure drop
0.5% NI, 4% NaCl

55. Phase behaviors of different ASP solutions after 1 week

56. Conclusions 4
Experimental results show that the ASP process with only 0.2% surfactant recovers 98% of the oil that is trapped after water-flooding. Good recoveries (>95%) were obtained in both dolomite sand pack and silica sand pack.
High salinity causes the phase separation for alkaline surfactant polymer solution. This results in loss of mobility control.
The simulation matches the experimental data.
High salinity can cause the phase separation of ASP solutions. This may result in loss of mobility control.