Abstract
Gas injection into the gas cap which is known as pressure maintenance or crestal gas injection is done to increase the reservoir pressure. Different types of gas may be injected in this method including producing gas, N2, CO2 etc. The injected gas is chosen base on the field development studies. Each of these gases has some advantage and disadvantages. Gas injection in naturally fractured reservoirs is a challenge which needs more investigation on this subject. This chapter summarizes the basic concepts of pressure maintenance and active mechanisms during pressure maintenance in naturally fractured reservoirs. Also, this chapter provides the essential concepts in simulation of pressure maintenance in fractured reservoirs.
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Abbreviations
- AD-OO:
-
Automatic differentiation-object oriented
- BHP:
-
Bottom-hole pressure
- EC:
-
European commission
- EDFM:
-
Embedded discrete fracture model
- EOR:
-
Enhanced oil recovery
- GMRES:
-
Generalized minimal residual method
- GOR:
-
Gas oil Ratio
- HFM:
-
Hierarchical fracture module
- ILU:
-
Incomplete lower/upper
- IOR:
-
Improved oil recovery
- IPR:
-
Inflow-performance relation
- MINC:
-
Multiple Interacting Continua
- MRST:
-
Matlab reservoir simulation toolbox
- MsRSB:
-
Multiscale restriction smoothed basis
- SAIGUP:
-
Sensitivity analysis of the impact of geological uncertainties on production forecasting
- A:
-
Area, m2
- B:
-
Formation volume factor, vol/vol
- C:
-
Concentration, mole/m3
- c:
-
Component
- cf:
-
Formation Compressibility, 1/psi
- D:
-
Depth, m
- \(D_{c,o} ,D_{c.g}\) :
-
Diffusion coefficient of component c in oil and gas, cm2/s
- \(D_{ij}\) :
-
Binary diffusion coefficient of components i and j, cm2/s
- Dg:
-
Gas diffusion coefficient, cm2/s
- \(D_{e,c}\) :
-
Effective diffusion coefficient for component c at matrix-fracture boundary, cm2/s
- \(D_{e,i}\) :
-
Effective diffusion coefficient for component i, cm2/s
- d:
-
Correlation coefficients
- e:
-
Correlation coefficients
- \(f_{o,c} ,f_{g,c}\) :
-
Fugacity of component c in oil and gas, psi
- \(f_{m,i}\) :
-
Fugacity of component i in phase m, psi
- F:
-
Formation resistivity factor
- G:
-
Gas in place, ft3
- H:
-
Fracture thickness in z-direction, m
- k:
-
Permeability, md
- kc:
-
Diffusion mass transfer coefficient of component c at matrix-fracture boundary, mole/(m2 s)
- Kc:
-
Equilibrium ratio of component c
- ki,j:
-
Binary interaction coefficient
- kro, krg,krw:
-
Relative permeability of oil, gas, and water
- krgcw:
-
Gas relative permeability at connate water
- krocw:
-
Oil relative permeability at connate water
- krwro:
-
Water relative permeability at residual oil saturation
- L:
-
Moles of oil per unit mole feed
- l :
-
Length of fracture, m
- m:
-
Cementation factor
- MWi:
-
Molecular weight of component i, g/gmole
- n1:
-
Exponent
- nc:
-
Number of components
- N:
-
Oil in place, bbl
- Nc,p:
-
Diffusion molar flux of component c at phase p, mole/(m2 s)
- nog,ng,nw,now:
-
Exponents on relative permeability curves
- \(P_{cog} ,P_{cow}\) :
-
Capillary pressure (oil–gas and oil–water), psi
- \(P_{c}^{0}\) :
-
Reference capillary pressure at reference interfacial tension, psi
- p:
-
Pressure, psi
- Pc:
-
Capillary pressure, psi
- pc,i:
-
Critical pressure of component i, psi
- Pi:
-
Parachor of component i
- po,pg,pw:
-
Pressure of oil, gas, and water, psi
- \(p_{ref}\) :
-
Reference pressure, psi
- \(\Delta p\) :
-
Pressure gradient, psi/ft
- \(q_{D,fm,c}\) :
-
Diffusion rate of component c at the matrix-fracture boundary, mole/s
- \(q_{C,fm,c}\) :
-
Convection mass transfer rate of component c at the matrix-fracture boundary, mole/s
- q:
-
Flow rate, ft3/day
- R:
-
Universal gas constant, cm3 MPa/(K. mole)
- Rs:
-
Solution gas oil-ratio, scf/stb
- Rs:
-
Produced gas oil-ratio, scf/stb
- Sgg:
-
Geometric mean of matrix and fracture gas saturation
- So,Sg,Sw:
-
Saturation of oil, gas, and water
- Sgr:
-
Residual gas saturation
- Sorg:
-
Residual oil saturation to gas
- Sorw:
-
Residual oil saturation to water
- Swc:
-
Critical water saturation
- Swir:
-
Irreducible water saturation
- Si:
-
Volume shift parameter in PR EOS
- t:
-
Time, day
- T:
-
Temperature, K
- Tc,i:
-
Critical temperature of component i, K
- To,Tg,Tw:
-
Transmisibilities of oil, gas, and water, mole.md/(m2.cp)
- \(T_{o,c}^{M} ,T_{g,c}^{M}\) :
-
Molecular transmisibilities of component c in oil and gas, mole/s
- Tr,i:
-
Reduced temperature of component i
- V:
-
Moles of vapor per unit mole feed
- Vp:
-
Pore volume
- \(\vec{v}\) :
-
Average gas stream velocity in the fracture, m/s
- \(\vec{v}_{o}\) :
-
Oil bulk velocity, m/s
- \(\vec{v}_{g}\) :
-
Gas bulk velocity, m/s
- \(v_{x} ,v_{y} ,v_{z}\) :
-
Fluid bulk velocities in x, y, and z directions, m/s
- Vr:
-
Bulk volume, m3
- Vp:
-
Pore volume, m3
- Vc,i:
-
Critical volume of component i, cm3/ mole
- W:
-
Fracture width in y-direction, m
- x,y,z:
-
Cartesian coordinates
- xc:
-
Mole fraction of component c in oil phase
- xj:
-
Mole fraction of component j in oil phase
- xi,m,xj,m:
-
Mole fraction of component i and j in phase m
- yc:
-
Mole fraction of component c in gas phase
- yj:
-
Mole fraction of component j in gas phase
- \(y_{c,mf}\) :
-
Mole fraction of component c in the gas phase at matrix-fracture boundary
- \(y_{c,f}\) :
-
Mole fraction of component c at the entrance of the fracture
- \(\left( {y_{i} } \right)_{m} ,\left( {y_{i} } \right)_{f}\) :
-
Mole fraction of component i in gas phase in matrix and fracture
- Zc:
-
Overall composition of component c
- Zj:
-
Overall composition of component j
- Zo,Zg,Zm:
-
Compressibility factor of oil, gas, and phase m
- \(z_{ref}\) :
-
Reference elevation, m
- We:
-
Water influx
- \({\alpha }_{s}\) :
-
Factor for considering skin-effect at matrix-fracture boundary
- \(\Omega _{ij}\) :
-
Collision diameter of the Lennard–Jones potential
- \(\sigma_{ij}\) :
-
Collision integral of the Lennard–Jones potential
- \(\Delta t\) :
-
Time step, day
- \(\Delta x,\Delta y,\Delta z\) :
-
Grid cells dimensions, m
- \(\gamma_{o} ,\gamma_{g} ,\gamma_{w}\) :
-
Specific gravity of oil, gas, and water, psi/ft
- \(\overline{{\gamma_{o} }} ,\overline{{\gamma_{g} }} ,\overline{{\gamma_{w} }}\) :
-
Average specific weight of oil, gas, and water, psi/ft
- \(\mu_{o} ,\mu_{g} ,\mu_{w}\) :
-
Viscosity of oil, gas, and water, cp
- \(\phi\) :
-
Porosity
- \(\phi_{0}\) :
-
Porosity at a reference pressure
- \(\phi_{o,c} ,\phi_{g,c}\) :
-
Fugacity coefficient of component c in oil and gas
- \(\rho_{o} ,\rho_{g} ,\rho_{w}\) :
-
Molar densities of oil, gas, and water, mole/cm3
- \(\rho_{r}\) :
-
Reduced density
- \(\rho_{m}\) :
-
Mixture molar density, mole/cm3
- \(\rho_{C,s}\) :
-
Critical density of component c, mole/cm3
- \(\rho_{mr}\) :
-
Reduced density of the mixture
- λ:
-
Mobility
- \(\sigma\) :
-
Interfacial tension, dyne/cm
- \(\sigma_{0}\) :
-
Initial interfacial tension corresponding to the read-in capillary pressure, dyne/cm
- \(\tau\) :
-
Tortuosity of the porous medium
- \(\omega_{i} ,\omega_{c}\) :
-
Acentric factor of component i and c
- c:
-
Component
- c:
-
Capillary
- c:
-
Critical
- f:
-
Fracture
- g:
-
Gas
- i:
-
Component
- i:
-
Grid block number in x-direction
- i:
-
Initial
- j:
-
Grid block number in y-direction
- k:
-
Grid block number in z-direction
- m:
-
Mixture
- m:
-
Phase
- m:
-
Matrix block
- o:
-
Oil
- p:
-
Phase
- p:
-
Produced
- p:
-
Pore
- r:
-
Reduced
- ref:
-
Reference
- t:
-
Total
- x,y,z:
-
X,y,z directions
- w:
-
Water
- l :
-
Iteration level
- L:
-
Time step
- M:
-
Molecular diffusion
- v:
-
Vapor
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Appendices
Appendices
5.1.1 Appendix A: Derivation of the Multiphase Flow Equations in Compositional Simulation
The multiphase flow equations govern compositional simulation will be derived. Basically, these equations are continuity equations for each component cover a volume element ΔxΔyΔz fixed in the space (Fig. 5.30) as following:
Component c can be transported across the volume element boundary by two mechanisms: diffusion and convection. These mechanisms, injection rate, production rate, and accumulation rate will be discussed in details next.
5.1.1.1 Convection Mechanism
Convective transport is the amount of material carried along by the bulk movement of the fluid. The driving force in convective transport is potential gradient. The molar rate in minus molar rate out of component c (mole/time) for x, y, and z directions due to convective transport in oil and gas phases are:
where
-
\(\rho_{o}\) and \(\rho_{g}\) are the molar densities of oil and gas.
-
ϕ is the porosity of the volume element.
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xc is the mole fraction of component c in the oil phase.
-
yc is the mole fraction of component c in the gas phase.
5.1.1.2 Diffusion (Molecular) Transport
Molecular transport, or diffusion, can also add material across the faces of the volume element. If No,c and Ng,c are the diffusion molar fluxes of component c (mole c per time per area) in oil and gas phases, these quantities have units of mole per area per time and represent the amount of transport by diffusion. Therefore, following the previous approach, the molar rate in minus molar rate out of component c for x, y, and z directions by diffusion are:
where
5.1.1.3 Production or Injection
Finally, production and/or injection of component c into the volume element are given by:
where \(q_{D,fm}\) and \(q_{C,fm}\) are diffusion and convection mass transfer between matrix and fracture at the matrix-fracture boundary.
5.1.1.4 Accumulation
The total mole of fluid in the volume element at any time is \(\phi \left( {\rho_{o} S_{o} + \rho_{g} S_{g} } \right)\Delta x\Delta y\Delta z\), and the mole of component c is \(\phi \left( {\rho_{o} S_{o} x_{c} + \rho_{g} S_{g} y_{c} } \right)\Delta x\Delta y\Delta z\). Therefore, the rate of accumulation of mole of component c is:
5.1.1.5 Flow Equations
The flow equations can be obtained by substituting Eqs. (5.137) to (5.143) into Eq. (5.136). If the resulting equations are divided by volume element \(\Delta x\Delta y\Delta z\) and applying limit when the volume element goes to zero, it becomes:
Or, in vector notation,
By substituting vo and vg from Eq. (5.138) and Nc,o and Nc,g from Eqs. (5.140) and (5.141) into Eq. (5.145), it becomes:
Equation (5.146) is a general case of compositional multiphase flow through porous media for each component in oil and gas phases. For the water phase, considering that hydrocarbon phases are immiscible in water, we have,
5.1.2 Appendix B: Discretizing the Flow Equations
The final form of the general hydrocarbon flow equations, as obtained in Appendix A (Eq. (5.147)), is as follows:
For simplicity, flow equations are discretized in x-direction only. The same procedure can be applied to y and z directions. Equation (5.148) in x-direction becomes:
5.1.2.1 Discretization Oil and Gas Convective Terms in x-direction
Defining oil and gas convective terms as:
Oil convective flux term will be discretized first. By substituting Eq. (5.150) into Eq. (5.149), the oil convective flux term in Eq. (5.149) in x-direction becomes:
Using central finite differences into Eq. (5.152):
where,
and,
By substituting Eqs. (5.154) and (5.155) into Eq. (5.152):
Gas convective flux term can be discretized by the same manner as:
5.1.2.2 Discretization the Oil and Gas Diffusive Flux Term in x-Direction
Oil diffusive flux term will be discretized first as:
Expanding the (i+1/2) and (i−1/2) term in Eq. (5.158):
Substituting Eqs. (5.159) and (5.160) in Eq. (5.158):
The same procedure can be used to discretize gas molecular diffusion term as:
5.1.2.3 Discretization the Accumulation Term
The accumulation term is discretized by using regressive finite differences in time as:
5.1.2.4 Final Form of Discretized Flow Equations
Substituting Eqs. (5.156), (5.157), (5.161), (5.162), and (5.163) into Eq. (5.149):
Multiplying Eq. (5.164) by the volume of the grid cell, \(V_{r,i,j,k} = \Delta y_{i,j,k} \Delta z_{i,j,k} \Delta x_{i,j,k}\), and rearranging, it becomes:
Now, defining the transmissibility terms for oil and gas phases as:
Substituting Eqs. (5.166) through (5.169) into Eq. (5.165), it becomes:
Equation (5.170) can also be written as:
Equation (5.171) is the final discretized form of the hydrocarbon flow equations in x direction. Following the same procedure, the discretized water flow equation in x direction becomes:
where
5.1.3 Appendix C: Newton–Raphson Method
The Newton–Raphson method to solve a set of nonlinear equations is described in detail. The problem consists of solving the following set of non-linear equations:
or,
where Fi, i = 1,2,…,n are the equations and x1, x2, …, xn are the unknowns. To develop the Newton–Raphson algorithm, all functions are first expressed as a Taylor series expansion about an arbitrary point (x1, x2, …,xn, F1, F2, …,Fn) as:
The objective is to find the roots of the equations by setting the left-hand sides of these n equations equal to zero. If initial values of the unknowns are assumed, the n equations of Eq. (5.157) can be solved for Δx1, Δx2,…, Δxn. This system of n equations may also be written as:
Equation (5.177) can also be expressed in matrix form as:
Equation (5.178) can be written as:
J is called the Jacobian of the n equations system. The system of Eq. (5.179) can be solved either by Gaussian elimination or by any appropriate procedure. The unknowns (x1, x2, …,xn) are updated after each iteration as:
where l is the iteration level. The iteration is terminated when \(\max \left( {\left| {\Delta x_{i} } \right|} \right) < tolerance\).
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Jamili, A., Izadpanahi, A., Aghaee Shabankareh, P., Azin, R. (2022). Gas Injection for Pressure Maintenance in Fractured Reservoirs. 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_5
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