Abstract
After primary and secondary recovery, substantial amounts of hydrocarbon remain entrapped by capillary forces. This phenomenon, known as capillary trapping. Different factors affect the microscopic trapping mechanism such as pore structure, wettability, capillary pressure, interfacial tension, relative permeability, initial saturation, and other properties of the rock and fluids. Understanding the amount of trapped phase is vital for different applications such as enhance oil recovery (EOR), enhanced gas recovery (EGR), and carbon capture and storage (CCS). In EOR and EGR, the purpose is reducing residual oil saturation, while for CCS, it is opposite, i.e. the target is maximising the amount of trapped CO2. There are two main capillary trapping mechanisms, snap-off and by-passing which are described in detail in this chapter. The laboratory methods and empirical mathematical models that are used to measure and predict the trapped phase saturation are discussed in this chapter. Furthermore, there are various techniques for the mobilization of the trapped hydrocarbon phase. Gas injection is one of the effective methods to remove the trapped phase. This chapter discusses some of the key aspects of phase trapping and mitigation methods.
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Notes
- 1.
Original Oil in Place.
- 2.
Enhance Oil Recovery.
Abbreviations
- OOIP:
-
Original Oil in Place
- S :
-
Saturation
- \(\varphi\) :
-
Porosity (%)
- k :
-
Permeability (m2)
- ρ :
-
Density
- CCS:
-
Carbon Capture and Storage
- CO2:
-
Carbon dioxide
- N2:
-
Nitrogen
- scCO2:
-
Supercritical carbon dioxide
- gCO2:
-
Gas carbon dioxide
- EOR:
-
Enhanced Oil Recovery
- Nc or Ca:
-
Capillary number
- PV:
-
Pore Volume
- IFT:
-
Interfacial Tension
- CT:
-
Computed Tomography
- USS:
-
Unsteady State Method
- IR:
-
Initial-Residual
- R2:
-
Coefficient of determination
- WAG:
-
Water alternating gas
- N:
-
Number of data point
- CDC:
-
Capillary desaturation curve
- Ctrap:
-
Trapping capacity
- S:
-
Saturation
- Si:
-
Initial saturation
- Sr:
-
Residual saturation
- Snw:
-
Non-wetting phase saturation
- Sw:
-
Wetting phase saturation
- Snwi:
-
Initial non-wetting phase saturation
- Snwr:
-
Residual non-wetting phase saturation
- Sgi:
-
Initial gas saturation
- Sgr:
-
Residual gas saturation
- Soi:
-
Initial oil saturation
- Sor:
-
Residual oil saturation
- Swi:
-
Initial water saturation
- Pc:
-
Capillary pressure
- \(S_{or}^{\exp }\) :
-
Experimental data of residual oil saturation
- \(S_{or}^{cal}\) :
-
Calculated data of residual oil saturation
- \(\overline{{S_{or}^{exp} }}\) :
-
Average of experimental data set of residual oil saturation
- \(S_{nwr}^{\max }\) :
-
Maximum residual non-wetting saturation
- \(S_{nwi}^{\max }\) :
-
Maximum initial non-wetting phase saturation
- \(S_{nwc}\) :
-
Critical non-wetting phase saturation
- Kr:
-
Relative Permeability
- Krw:
-
Wetting phase relative permeability
- Krnw:
-
Non-wetting phase relative permeability
- v :
-
Velocity (m/s)
- μ :
-
Viscosity (Pa s)
- σ :
-
Interfacial tension (mN/m)
- γ :
-
Surface tension
- θ :
-
Contact angle (degree)
- N Bo :
-
Bond number
- Δρ:
-
Density difference
- g :
-
Acceleration due to gravity
- µi:
-
Invading fluid viscosity
- μd:
-
Displacing fluid viscosity
- rb:
-
Radius pore body
- rt:
-
Radius pore throat
- ΔP:
-
Pressure difference
- C :
-
Land trapping constant
- R :
-
Radius
- β :
-
Heterogeneity factor
- L :
-
Length of the doublet
- q w :
-
Water flow rate
- v :
-
Velocity
- µo:
-
Oil viscosity
- μw:
-
Water viscosity
- M :
-
Mobility ratio
- α and β:
-
Spiteri et al. trapping constant
- a and b:
-
Ma and Youngren trapping constant
- \(V_{oi}\) :
-
Volume of displaced water with oil during primary drainage
- \(V_{DV}\) :
-
Dead volume of cell
- \(V_{wf}\) :
-
Volume of displaced oil during water flooding
- \(M_{dry}\) :
-
Mass of the dry core
- \(M_{dragnage}\) :
-
Mass of the core after drainage
- \(M_{wf}\) :
-
Mass of the core after water flooding
- g :
-
Gas
- o :
-
Oil
- w :
-
Water
- i :
-
Initial
- r :
-
Residual or trapped
- nw :
-
Non-wetting phase (oil or gas)
- c :
-
Critical
- exp :
-
Experimental
- cal :
-
Calculated
- max :
-
Maximum
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Appendix: Derivation of Velocity Ratio Expression
Appendix: Derivation of Velocity Ratio Expression
The purpose of this Appendix is to drive the velocity ratio expression in the pore doublet model, which determine the interface position (Fig. 10.25).
The magnitude of capillary pressure affect the velocity of the interface in both capillary tube. The static capillary pressure function (Pc equation) is defined as Eq. 10.23.
where σ is the interfacial tension between invading and invaded fluid, θ is the advancing contact angle and R is the radius of the capillary.
Furthermore, the volumetric flow rate in either path is given by Hagen-Poiseuille (H-P) equation:
where R is the radius of the capillary, L is the length of the flow path of the doublet, assumed to be the same in both branches and μ is the viscosity, assuming that both fluids have the same viscosity. The magnitude of viscose pressure drop can be calculated using Eq. 10.24, if the flow rate was known. Equation 10.24, implies the assumptions of cylindrical capillaries of circular cross-section and of fully developed and steady laminar flows that none of which is likely to be met in reality.
The total volumetric flow rate through the doublet, if the water is supplied at the volume flow rate, qw, to the doublet can be written as:
where ql is volume flow rates in capillary 1 and q2 is volume flow rates in capillary 2. The flow direction from left to right are taken with a positive sign and in reverse direction with a negative sign. It is assumed that the interfaces advance simultaneously in both capillaries of pore doublet.
The pressure drop across each capillary is the sum of the capillary pressure and the viscous pressure drop. Since the two capillaries are parallel, the net pressure difference between the two branch points must be the same when taken over either of the two capillaries 1 and 2.
And so
In Eq. 10.26, the capillary pressure is positive for imbibition process and negative for drainage one.
Equation (10.27) can be rearranged as:
Substitute Eqs. (10.28) into (10.25):
So Eq. (10.29) can be rearranged as:
Then, \(\Delta P_{2}\) can be found using Eq. (10.30).
Equation (10.25) it can be rearranged as:
Then Eqs. (10.32) together with Eq. (10.31) results in:
Equation 10.33 can be simplified to:
Dividing this equation by R14 and multiplying by \(\left( {R_{1}^{4} + R_{2}^{4} } \right)\):
So the equation of q1 and q2 are as follows:
Then expressions of the velocities, v1 and v2, will be obtained by dividing each flow rate by its respective cross-sectional area (\(\frac{{\pi D_{1}^{2} }}{4}\) and \(\frac{{\pi D_{2}^{2} }}{4}\)):
And
So dividing these two velocity to find the ratio of velocity:
Dividing this expression by \(R_{2}^{2} \sigma \cos \theta\) and multiplying by \(4\mu LR_{1}\)
Finally, Eq. 10.19 can be further simplified to:
In which
And
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Kazemi, F., Azin, R., Osfouri, S. (2022). Capillary Phase Trapping. In: Azin, R., Izadpanahi, A. (eds) Fundamentals and Practical Aspects of Gas Injection. Petroleum Engineering. Springer, Cham. https://doi.org/10.1007/978-3-030-77200-0_10
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