Abstract
In this paper, two-grid finite element method for the steady dual-permeability-Stokes fluid flow model is proposed and analyzed. Dual-permeability-Stokes interface system has vast applications in many areas such as hydrocarbon recovery process, especially in hydraulically fractured tight/shale oil/gas reservoirs. Two-grid method is popular and convenient to solve a large multiphysics interface system by decoupling the coupled problem into several subproblems. Herein, the two-grid approach is used to reduce the coding task substantially, which provides computational flexibility without losing the approximate accuracy. Firstly, we solve a global problem through standard Pk − Pk− 1 − Pk − Pk finite elements on the coarse grid. After that, a coarse grid solution is applied for the decoupling between the interface terms and the mass exchange terms to solve three independent subproblems on the fine grid. The three independent parallel subproblems are the Stokes equations, the microfracture equations, and the matrix equations, respectively. Four numerical tests are presented to validate the numerical methods and illustrate the features of the dual-permeability-Stokes model.
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1 Introduction
Over the last few years, Stokes-Darcy and related multiphysics problems have notable importance due to their practical applications such as groundwater problems in karst aquifers [1, 2], industrial filtration [3], petroleum extraction [4], the interaction between surface and subsurface flows [5,6,7,8,9], blood flow in the artery and vein [10,11,12], and fluid-structure interactions [13, 14]. For these practical applications, researchers usually used the traditional Stokes-Darcy model extensively over the past few decades.
On the other hand, the hydraulically fractured reservoir contains more than half of the world remaining petroleum resources, and the extraction of the hydrocarbon occurs from fractured formations, including naturally fractured reservoirs (NFRs), coal bed methane (CBM), and tight fractured gas reservoirs [15,16,17,18]. Nowadays, the universal requirements of the energy demands are met by the petroleum industry which is extracted from the NFRs. But it is believed that the economic hydrocarbon extraction from the NFRs depends on the reservoir’s intrinsic properties, especially fracture permeability [15, 19, 20]. Regarding the fact that naturally fractured reservoirs (NFRs) are intrinsically heterogeneous at all scales, a large number of reservoir contains two different scale flow mechanisms which cannot be modeled explicitly, nor homogenized in the reservoir simulation model [21]. For example, in the shale/tight oil/gas reservoir, the matrix permeability is 105 to 107 times smaller than the microfracture permeability while the matrix porosity is usually 102 to 103 times larger than the microfracture porosity [22,23,24,25,26]. Hence, a dual-permeability/porosity model must incorporate a transfer function between matrix and fracture in order to predict the optimal recovery mechanism from the fractured reservoir [21]. In the dual-porosity conceptualization, the tight matrix is considered with the large storativity of fluid, while the networks of fractures are assumed with high fluid conductivity [27]. As a result, the matrix system and the microfracture region can be adopted as two overlapping but interacting media with different hydraulic and transport properties [23, 28].
To this end, the first dual-porosity/dual-permeability fluid flow model (DPM) was proposed by Barenblatt et al. in 1960 by considering dual-continua for naturally fractured reservoirs [29]. The dual-continuum approach provides a mathematical framework for the fluid flow and mass exchange between matrix block and microfracture region. This concept was originally applied to the reservoir engineering by Warren and Root in 1963 [30] to characterize and simulate the flow pattern in the realistic naturally fractured reservoir. Moreover, they introduced a shape factor in the mass transfer function, which is one of the key parameter in the pressure transient analysis [30,31,32]. Based on the model proposed by Warren and Root [30], the dual-permeability/porosity fluid flow model concept has been considered to simulate flows through naturally fractured reservoirs because of the specificity of those media: fluids are mainly stored in the matrix region (primary pores) and flow to the wellbore through the fracture system (secondary pores) [33,34,35,36,37,38,39,40]. The matrix block, considered as a stagnant medium with high porosity and lower permeability, acts as the primary storage of fluid. The fracture region consists of lower porosity with higher permeability and feeds the wellbore or conduits while it receives the fluid from the matrix region only [23, 24, 34, 41, 42]. Besides, the dual-porosity model can be improved by considering integrated discrete fracture networks [43].
It is worthwhile noting that the Stokes-Darcy fluid flow model cannot describe the heterogeneous intrinsic properties in the groundwater flow region since it deals with single permeability in the porous medium. To model the multiple porosity, various permeability and different intrinsic properties of the naturally fractured reservoir, dual-porosity and dual-permeability fluid flow model is the appropriate choice. Hence, the dual-porosity-Stokes model is more effective and appropriate for realistic reservoir engineering, which was recently introduced by Hou et al. in [23]. Later, Shan et al. studied the dual-porosity-Stokes system by using partitioned time-stepping method for Beavers-Joseph interface condition [26]. On the other hand, Mahbub et al. investigate the dual-porosity-Stokes fluid flow model by using stabilized mixed finite element method in [28]. The dual-permeability-Stokes model can be used to study the flow and transport processes in underground natural-resources recovery, especially petroleum extraction, tight/shale oil/gas recovery, carbon sequestration, geothermal system, waste storage, contaminant remediation and so on [22,23,24, 26, 28, 44,45,46,47,48,49,50].
In practice, there are two main approaches used for solving the multiphysics problems. The first approach is to solve a coupled problem directly, and the second one is to decouple the whole problem into several subproblems and then apply an appropriate technique to solve local problems individually. Furthermore, to solve the coupled problem through decoupling process, many effective methods have been developed over the last few years, such as, domain decomposition methods [51,52,53,54,55,56], preconditioning techniques [57], partitioned time-stepping methods [58,59,60,61], two-grid and multi-grid methods [62,63,64,65,66,67,68,69,70,71,72,73,74,75,76], Lagrange multiplier methods [7, 77, 78], discontinuous Galerkin finite element methods [6, 79, 80], finite volume methods [81, 82], mortar finite element methods [83, 84], artificial compression methods [85, 86] and many others.
The two-grid finite element method is one of the most popular technique to study a large stationary coupled problem through decoupling approach. This method was first introduced by Xu [62, 63] for the non-symmetric and nonlinear elliptic problems. Later, the two-grid method was introduced for decoupling the Stokes-Darcy fluid flow model in [64] by Mu and Xu. Cai et al. used a two-grid algorithm to solve Navier-Stokes-Darcy model in [65]. To solve the mixed Stokes-Darcy model with optimal error estimates, some modified methods are discussed and analyzed in [66,67,68]. Recently, a low order stabilized two-grid finite element method was proposed and numerically solved by Yu et al. [69] for the Stokes-Darcy fluid flow model. Moreover, Zhang et al. reported two-grid method for the Stokes-Stokes coupled problem in [70]. Two-grid method is a type of decoupling approach to solve a coupled problems into two-levels, such as in coarse grid mesh and fine grid mesh where h << H [71]. The key idea is to use a coarse grid mesh to produce the manufactured approximate solution for the linear/nonlinear problems, and then use it as the initial guess on the fine grid. Furthermore, the two-grid method provides a decoupling approach to solve the global problems into several subproblems independently by using the most appropriate numerical techniques and preconditions. Numerical results suggest that the decoupled two-grid algorithm achieves similar approximate accuracy as the coupled algorithm.
In this paper, the dual-permeability-Stokes interface system is solved numerically by using the two-grid method. To couple the Stokes equation and the dual-permeability equations, four physically valid interface conditions are utilized. The first interface condition describes the no-communication of fluid between Stokes and matrix region. Second and third interface conditions are mass conservation and balance of normal forces, respectively. The fourth interface condition is Beavers-Joseph-Saffman interface condition [87, 88]. To our best of knowledge, this is the first work to solve the stationary dual-permeability-Stokes fluid flow model through two-grid method. On the coarse mesh, a coupling problem is solved by using the standard Pk − Pk− 1 − Pk − Pk finite element approximation. On the fine mesh, three decoupled subproblems are solved independently through parallel computation as: the Stokes problem, the microfracture, and matrix equations. Moreover, the Stokes problem and microfracture equations are separated by the interface. On the other hand, microfracture and matrix equations are decoupled through the mass exchange terms. Two-grid algorithm is widely used due to its simplicity and computational flexibility, such as significant CPU time saving without losing approximate accuracy and less computer memory for meshes and algebraic systems. Furthermore, the two-grid method provides a simple way to partition a large steady-state coupled system into several subproblems, which can be computed in parallel. The variational formulation is reported, the optimal error estimate is derived for the coupled and two-grid schemes. Four numerical experiments are illustrated to validate the numerical methods and show the features of the dual-permeability-Stokes fluid flow model.
The rest of the paper is organized as follows. A dual-permeability-Stokes fluid flow model is presented in the next Section. In Section 3, a two-grid algorithm for the dual-permeability-Stokes fluid flow model is given and the optimal error estimates are derived. Four numerical experiments are presented on the support of the theoretical analysis in Section 4. Finally, a short conclusion is reported in Section 5.
2 Model equations
As illustrated in Fig. 1, we consider a composite domain consisting of nonoverlapping conduit subdomain Ωc and the dual-permeability subdomain Ωp, where Ωc,Ωp ⊂ Rd(d = 2 or 3) are smooth, and bounded. Here Ωc ∩Ωp = ∅, \(\overline { {\Omega } }_{c}\cup \overline {\Omega }_{p}=\overline {\Omega }\), ∂Ωc ∩ ∂Ωp = Γ is the interface.
The below dual-permeability-Stokes fluid flow model is the steady-state version of the time-dependent dual-porosity-Stokes interface system which was studied in [23, 26, 28].
In the conduit domain Ωc, the fluid flow is governed by the stationary Stokes equations which can be written as
In the naturally fractured reservoir subdomain Ωp, the fluid flow is modeled by the dual-permeability fluid flow models, which is composed of matrix and microfracture equations [23, 26] as follows:
Here, \(\vec {u}\) is the fluid velocity and p is the pressure, ν is the kinematic viscosity, \(\vec {f}\) is the external force on the fluid domain, φm and φf are the pressure in matrix and fracture region, km and kf represent the intrinsic permeability in matrix and fracture regime, μ is the dynamic viscosity. \(\frac {\sigma k_{m}}{\mu }(\varphi _{m}-\varphi _{f})\) represents the mass exchange term between matrix and microfractures with σ is a shape factor characterizing the morphology and dimension of the microfractures. qp is the sink/source term.
The matrix region is the main storage of fluid, which supplies the fluid to the fracture continua. On the other hand, the fracture region feeds the conduit or wellbore while receiving the fluid from the matrix only. Hence, the matrix block does not interact directly with the conduit or wellbore. As a result, we utilize no-communication interface condition between matrix and conduit region [23, 26]. Moreover, three traditional coupling conditions are applied to describe the interface between microfracture and conduit region. Hence, the coupling conditions for the dual-permeability-Stokes fluid flow model can be written as:
-
No-communication of fluid between matrix block and conduit region:
$$ \begin{array}{@{}rcl@{}} -\frac{k_{m}}{\mu}\nabla\varphi_{m}\cdot \hat{n}_{p}&=&0\quad\quad \text{on} {\Gamma}. \end{array} $$(2.8) -
The conservation of mass on the interface Γ:
$$ \begin{array}{@{}rcl@{}} \vec{u}\cdot \hat{n}_{c} &=& \frac{k_{f}}{\mu}\nabla\varphi_{f}\cdot \hat{n}_{p} \quad\quad \text{on} {\Gamma}. \end{array} $$(2.9) -
Balance of normal forces on the interface Γ:
$$ \begin{array}{@{}rcl@{}} p-\nu \hat{n}_{c} \frac{\partial \vec{u}}{\partial \hat{n}_{c}} &=&\frac{\varphi_{f}}{\rho} \quad \text{on} {\Gamma}. \end{array} $$(2.10) -
The Beavers-Joseph-Saffman-Jones coupling condition on the interface Γ:
$$ \begin{array}{@{}rcl@{}} -\nu \tau_{i} \frac{\partial \vec{u}}{\partial \hat{n}_{c}} &=&\frac{\alpha \nu \sqrt{d}}{\sqrt{{\text{tr}({\Pi})}}}\vec{u}\cdot \tau_{i} \quad 1\leq i \leq (d-1) \quad \text{on} {\Gamma}, \end{array} $$(2.11)
where \(\hat {n}_{c}\) and \(\hat {n}_{p}\) denote the unit outward normal vectors on ∂Ωc and ∂Ωp, respectively. On the interface Γ, the unit outward normal vector satisfies \(\hat {n}_{c}=-\hat {n}_{p} \). ρ is the fluid density, α is a constant parameter depending on the properties of the porous medium and τi(i = 1,...,d − 1) denote the unit tangential vectors on the interface Γ. π = kfI is the intrinsic permeability of the fracture medium.
For any arbitrary domain D ⊂ Rd(d = 2,3), the L2(D) inner product and its norm are equipped with (⋅,⋅)D and ∥⋅∥0,D, respectively. The norm of the Hilbert spaces Hk(D) can be denoted by ∥⋅∥k,D, for scalar and vector-valued functions.
Define the following spaces:
The space W is equipped with the following norm: \(\forall \textbf {u}=(\vec {u},\varphi _{f}, \varphi _{m})\in W\),
The weak formulation of the dual-permeability-Stokes fluid flow model (2.1)–(2.11) is as follows: find \( \textbf {u}=(\vec {u},\varphi _{f}, \varphi _{m})\in W\) and p ∈ Q such that
where
The well-posedness of the dual-permeability-Stokes fluid flow model can be easily derived by following [23].
3 Decoupled scheme and error estimates
In this section, two-grid decoupled algorithm and the error estimates are presented for the dual-permeability-Stokes model.
Let \({{\Pi }^{h}_{i}}\) be a regular triangulation of Ωi,i = c,p consisting of K elements with mesh size function h(x), whose value is the diameter BT. Let Wh = Hc,h × Hpf,h × Hpm,h ⊂ W and Qh ⊂ Q be the finite element subspaces.
For the finite element spaces Hc,h × Hpf,h × Hpm,h × Qh, the following error estimates for the dual-porosity-Stokes model holds: \( \forall (\vec {v}, \psi _{f}, \psi _{m}, q) \in W({\Omega }) \times H^{1}({\Omega }) \) there exists approximation \( I_{h}\vec {v} \in H_{c,h} \), Lhψf ∈ Hpf,h, Jhψm ∈ Hpm,h and ρhq ∈ Qh
where mapping \( \rho _{h} : Q \rightarrow Q_{h} \) satisfies (p − ρhp,q) = 0, p ∈ Q and q ∈ Qh.
The coupled finite element algorithm for (2.13)–(2.14) based on the subspaces (Wh,Qh) follows:
3.1 Coupled finite element scheme
Algorithm 1 (Coupled scheme): To find \(\textbf {u}_{h}=(\vec {u}_{h},\varphi _{fh},\varphi _{mh})\in W_{h}\) and ph ∈ Qh such that we have
Remark 3.1
For convenience, we rewrite the variational form (2.13)–(2.14) by using the bilinear form as an equivalent formulation
and the coupled scheme (3.5)–(3.6) can be written as
to derive the stability and convergence of the coupled algorithm.
Theorem 3.1
The bilinear form \( {\mathscr{B}}_{h} \left ((\vec {u}_{h}, \varphi _{fh}, \varphi _{mh}, p_{h}),(\vec {v}_{h},\psi _{fh}, \psi _{mh}, q_{h})\right ) \) satisfies the continuity
and the coercivity
where β is a positive constant depending only on Ω.
Remark 3.2
By following [23, 64, 69, 74, 89], the continuity and coercivity for the coupled scheme of the dual-permeability-Stokes fluid flow model can be achieved. To prove the stability for the coupled system of the dual-permeability-Stokes interface system is not our main concern. Moreover, for this coupled system, one needs to solve a global problem, which produces huge complexities in solving the resulting linear systems. Therefore, a two-grid method is designed to solve a large system by decoupling the coupled problem into several parallel subproblems in the following way.
3.2 Two-grid decoupled scheme
Algorithm 2 (Two-grid scheme):
Step 1. Firstly, we solve the coupled finite element problem on a coarse grid H. To find \(\textbf {u}_{H}=(\vec {u}_{H},\varphi _{fH},\varphi _{mH})\in W_{H}\subset W_{h}\) and pH ∈ QH ⊂ Qh such that
Step 2. Using the approximate solution of the coarse grid, we solve three decoupled subproblems in the fine grid h << H. To find \( \textbf {u}^{h}=(\vec {u}^{h},{\varphi _{f}^{h}},{\varphi _{m}^{h}}) \in W_{h}, {p}^{h} \in Q_{h}\) such that
It is not difficult to verify that the system (3.13)–(3.14) is equivalent to three decoupled subproblems: one is a Stokes problem on Ωc and the other two are the matrix and microfracture equations on Ωp. In fact, on the fine grid, the discrete Stokes problem is solved in Ωc: find \( {\vec {u}}^{h} \in H_{c,h}, {p}^{h} \in Q_{h}\) such that
And in the porous flow domain Ωp, we only need to solve the matrix and microfracture equations in parallel: find \( {\varphi }_{m}^{h} \in H_{pm,h}\) such that
and find \( {\varphi }_{f}^{h} \in H_{pf,h}\) such that
3.3 Error estimates
This section deals with the optimal convergence analysis of the proposed coupled scheme and two-grid method for the dual-permeability-Stokes fluid flow model. Hence, the present analysis is carried out for Algorithm 1 and Algorithm 2.
The following error estimates hold for \((\vec {u}_{h},p_{h},\varphi _{fh},\varphi _{mh})\) by assuming the regularity \(\vec {u}\in (H^{2}({\Omega }_{c}))^{2}, {\varphi _{f}} \in H^{2}({\Omega }_{p}),{\varphi _{m}} \in H^{2}({\Omega }_{p})\) and \(p\in H^{1}({\Omega }_{c})\) for Algorithm 1 [23, 64, 69, 73, 74, 89].
Theorem 3.2
and
Consequently, on the coarse mesh, one can obtain
proof
Setting \( (\vec {v}, \psi _{f}, \psi _{m}, q) = (\vec {v}_{h}, \psi _{fh}, \psi _{mh}, q_{h}) \) in (3.7) and subtracting (3.7) from (3.8), we obtain
By plugging interpolation error \( (\vec {e}, \zeta , \xi , \eta )= (I_{h}\vec {u}-\vec {u}_{h}, L_{h}\varphi _{f}-\varphi _{fh}, J_{h}\varphi _{m}-\varphi _{mh}, \rho _{h}p-p_{h} ) \), using the estimates (3.1)–(3.4) and the continuity (3.9), we obtain
Now
the use of triangle inequality
which provides the desired H1(Ω) error estimate (3.19).
We define discrete divergence free space \( V= \lbrace \vec {v} \in H_{c}~ \mathrm {such~ that~} \text {div} \vec {v}=0 ~\text {in}~ {\Omega }_{c} \rbrace \).
Let \( (\vec {u}, \varphi _{f}, \varphi _{m}, p) \) and \((\vec {u}_{h}, \varphi _{fh}, \varphi _{mh}, p_{h}) \) be the solution of (3.7) and (3.8), respectively. Find \( (\vec {w}, \xi _{f}, \xi _{m}, r) \in V \times H_{pf} \times H_{pm}\times Q \) such that \( (\vec {v}, \psi _{f}, \psi _{m}, q)\in (W, Q) \) satisfies
The solution of the dual-problem achieves the following regularity condition
Plugging \( (\vec {v}, \psi _{f}, \psi _{m}, q) = (\vec {u}-\vec {u}_{h}, \varphi _{f}-\varphi _{fh}, \varphi _{m}-\varphi _{mh}, p-p_{h})\) in the dual-problem (3.26) and using (3.1)–(3.4), continuity result (3.9), equation (3.25), we can get
finally, the results (3.20) follows by (3.27).
On the other hand, the estimate for the coarse mesh (3.21) can be obtained immediately from the above H1(Ω) and L2(Ω) error estimate by replacing h by H. □
Next, we derive the error estimate for the two-grid method of the dual-permeability-Stokes fluid flow model.
Theorem 3.3
Let \((\vec {u}_{h},p_{h},{\varphi }_{fh},{\varphi }_{mh})\) and \((\vec {u}^{h},p^{h},{\varphi ^{h}_{f}},{\varphi }^{h}_{m})\) be the solutions of Algorithm 1 and Algorithm 2, respectively. Then the following error estimates hold
proof
To derive the error estimates of the proposed two-grid method, the idea of Mu and Xu [64] is followed by comparing Algorithm 1 and Algorithm 2 on the same fine grid h, we obtain
Plugging \(\textbf {v}_{h}=(0,0,{\varphi }_{fh}- {\varphi }_{f}^{h})\) into the equation (3.31), we get
It is easy to estimate the first term in the right-hand side of (3.33)
To estimate the second term in the right-hand side of (3.33), an auxiliary problem is restated which is given in [64, 69, 74]. Let \(\theta \in H^{1}({\Omega }_{c})\) satisfy the following equations:
Let us suppose that \(H_{00}^{1/2}({\Gamma })=[L^{2}({\Gamma }),{H^{1}_{0}}({\Gamma })]_{1/2}\) be the interpolation space [70]. Then we have the following inequalities:
For all qH ∈ QH, \(b(\vec {u}_{h}-\vec {u}_{H},q_{H})=0\), thus, let 𝜃H be the interpolation of 𝜃 from Q onto QH, then,
Therefore, by combining all the above estimates, we get
Similarly, plugging \(\textbf {v}_{h}=(0,{\varphi }_{mh}- {\varphi }_{m}^{h},0)\) into the equation (3.31) yields
The combination of above two estimates (3.40)–(3.41) provides exactly the desired convergence analysis (3.29) for the dual-permeable region.
On the other hand, to derive the optimal error estimates for the velocity and pressure in the conduit region, the following auxiliary problem is introduced in the microfracture and matrix region: for any given \(\vec {v}_{h}\in H_{c,h}\), find \({\Phi } \in H^{1}({\Omega }_{p})\) satisfying
which yields
Since Γ is smooth, for any \(\vec {v}_{h}\in H_{c,h}\), we can achieve
Plugging \(\textbf {v}_{h}=(\vec {v}_{h},0,0)\) into the equations (3.31) and (3.32), to obtain
The right-hand side of (3.45) can be stated equivalently as:
By using (3.29), the right-hand side of the equation (3.47) can be estimated as:
It is obvious that
Suppose that ΦfH ∈ Hp,H be the linear interpolation of Φ, then,
The last term of (3.47) can be controlled as
Then, finally, we summarize to obtain
Thus,
By the inf-sup condition, we can have
Hence, the error estimate (3.30) is also proved. □
By using the triangle inequality and Theorem 3.3, it is easy to obtain the following corollary.
Corollary 3.1
Let \((\vec {u}^{h},p^{h}, {\varphi }^{h}_{f},{\varphi ^{h}_{m}})\) be the solution of Algorithm 2, we have the following optimal error estimates
Specifically, when choosing H = O(h1/2), we have
4 Numerical experiments
In this section, four numerical examples are presented to validate the proposed two-grid method and illustrate the feature of the dual-permeability-Stokes multiphysics interface system. In the first numerical test, the optimal convergence order is obtained for an analytical solution. In the second example, we test accuracy for a smaller value of the intrinsic permeability with relative error. In the third example, the flow speed and streamlines are illustrated on a horizontal open-hole with production wellbore. The fourth experiment demonstrates the lid-driven cavity flow. To compute the Stokes problem, MINI element pair (P1b,P1) is used. In the porous medium, P1 Lagrangian finite elements are used to compute the matrix and microfracture flow pressure. On the other hand, we also utilize Hood-Taylor element (P2,P1) for the Stokes velocity and pressure, and quadratic element P2 is used for the microfracture and matrix pressure. Moreover, the relation between the coarse mesh H and the fine mesh h is chosen as h = H2.
For simplicity, the coupled algorithm is denoted by SFEM, and the two-grid algorithm by TGM. The numerical experiments are conducted on an ASUS X555LF-XO040D laptop with 8 GB RAM and Core i5 configuration. On the other hand, we utilize open source FreeFem++ software to conduct and implement the numerical experiments [90].
4.1 Analytical solution test: 1
In the first numerical test, the physical parameters ρ, ν, α, μ, km, kf are simply taken as 1.0. The computational domains are defined as Ωc = (0,1) × (1,2) and Ωp = (0,1) × (0,1) with interface Γ = (0,1) ×{1}.
The below analytical solution satisfies the Beavers-Joseph-Saffman interface condition
The force term and the boundary condition are determined by this analytical solution.
In Tables 1 and 2, the error obtained comparing the exact solution and approximate solution for SFEM and TGM, respectively by utilizing P1b − P1 − P1 − P1 finite elements. Table 1 shows that microfracture and matrix pressure H1-norm, Stokes velocity H1-norm, and pressure L2-norm obtain O(h) order convergence accuracy. On the other hand, Table 1 shows that one-level method consumes more CPU time. In Table 2, the TGM approximate accuracy is illustrated by choosing h = H2 which shows that \(\nabla \varphi _{f}, \nabla \varphi _{m}, \nabla \vec {u}\) and p in the L2-norm achieve optimal convergence order. As expected, TGM consumes less CPU time than SFEM. Furthermore, we present the approximate accuracy by using P2 − P1 − P2 − P2 finite elements in Table 3 and achieve almost second order accuracy in Stokes velocity, microfracture and matrix pressure H1-norm and Stokes pressure L2-norm, respectively.
4.2 Analytical solution test: 2
In the second numerical test, we choose the smaller value for the microfracture and matrix intrinsic permeability kf = 0.1 and km = 0.001, respectively. Moreover, other constants ρ, ν,α,μ are simply chosen to be 1.
The following exact solution satisfies the Beavers-Joseph-Saffman interface condition
The force term and boundary conditions are determined by the exact solution. To perform this numerical test, we utilize P1b − P1 − P1 − P1 finite elements.
In Table 4, the approximate accuracy for the relative error is listed for TGM by choosing microfracture intrinsic permeability kf = 0.1 and matrix intrinsic permeability km = 0.001. Table 4 shows that we achieve first-order convergence accuracy for the microfracture pressure, matrix pressure, Stokes velocity, and Stokes pressure, respectively.
4.3 Horizontal wellbore with open-hole completion
In this experiment, the flow speed, magnitudes, streamlines and distribution of pressure are illustrated in a horizontal production wellbore with open-hole completion. The horizontal open-hole with vertical production wellbore has enormous applications in the hydrocarbon extraction process, and many other areas of the naturally fractured reservoirs [23, 24, 34, 37,38,39, 41, 42].
To perform the simulation of the horizontal wellbore with open-hole completion [23, 37,38,39], the geometrical shape is considered as shown in Fig. 2 [23]. The dual-porous domain is taken as Ωp = [0,2]2 where the horizontal wellbore with open-hole completion lies in between the square domain which is assumed as Ωc = [0.6,1.4] × [0.9,1.1]. The fluid flow from the microfracture to the conduit passes through the interface Γcp satisfying four interface conditions described in the equations (2.8)–(2.11).
The boundary conditions of the current experiment are imposed in the following way. On outside of the outflow boundary Γout, no-direct communication condition is imposed between the matrix and fracture pressure which implies to \( -\frac {k_{m}}{\mu }\nabla \varphi _{m}\cdot \hat {n}_{p}=0 \) and \( -\frac {k_{f}}{\mu }\nabla \varphi _{f}\cdot \hat {n}_{p}=0 \). On the inside of the outflow boundary Γout, homogeneous Neumann boundary condition \( (-p \mathbf {I}+\nu \nabla \vec {u}) \cdot \hat {n}_{c}=0 \) is applied for free outflow. The vertical wellbore, known as production well is connected with the horizontal well on the boundary Γout, where the fluid flow can pass out through it.
The parameters value of the model are considered as intrinsic permeability kf = 2.5 × 10− 1, km = 10− 9, dynamic viscosity μ = 2.5 × 10− 3, kinematic viscosity ν = 5.0 × 10− 2, density ρ = 5.0 × 10− 2, constant parameter α = 2.5 and shape factor σ = 0.25. The microfracture pressure on the boundary of the dual-permeability medium is considered as φf = 5 × 101 and the matrix pressure φm = 104. The mesh size is uniform in the domain and chosen as hmax = 0.03.
The fundamental properties of the naturally fractured reservoir consisting of the dual-porosity/permeability medium state that, the matrix block serves as the main storage of the fluid while the microfracture region is fed by the matrix region. The horizontal wellbore is fed by the microfracture, which shows that fluid flow and mass exchange between this medium is sequential. Moreover, the fluid flow of the matrix region does not directly communicate with the horizontal wellbore. Figure 3 (left) demonstrates the flow between microfracture and horizontal wellbore. The fluid flows from the matrix to microfracture and then microfracture to the horizontal wellbore. As expected, the faster flow is located in the horizontal wellbore, where the production well is attached. The pattern of the streamlines also indicate that the fluid is flowing from the microfracture to the horizontal open-hole towards the production wellbore. Figure 3 (right) represents the fluid flow and streamlines in the matrix region. In Fig. 4, the distribution of pressure is illustrated in the microfracture and matrix region, respectively, which appear reasonable. It is worthwhile noting that Figs. 3 and 4 are generated by using P1b − P1 − P1 − P1 finite elements.
In Fig. 5, we demonstrate magnitudes, contour and streamlines around a horizontal wellbore for the comparison purpose by using P2 − P1 − P2 − P2 finite elements which appear similar as Fig. 3. The rest of the numerical simulations in this example are conducted through P1b − P1 − P1 − P1 finite elements.
In Fig. 6, the impact of the larger value of permeability is presented on the matrix region by gradually increasing the permeability km = 10− 8 and km = 10− 7, respectively. As expected, the increase of the permeability produces faster flow speed in the matrix region, which can be seen in the contour color bar.
In naturally fractured reservoir engineering, shape factor σ plays an essential role in the matrix-fracture transfer function. The rate of mass transfer from the matrix to the fracture is directly proportional to the shape factor [31, 32]. The value of shape factor generally varies from 0 to 1, where the larger value of the shape factor generates faster flow, and the smaller value produces slower flow. Figure 7 illustrates the flow rate of the matrix region for the parameter value σ = 0.009 and σ = 0.1, respectively. From the figures, one can obviously observe that the smaller value of the shape factor generates slower flow and larger value produces faster fluid flow. The above numerical results illustrate the complicated flow characteristics and exclusive feature around the horizontal wellbore with open-hole completion.
4.4 Modified lid-driven cavity flow
In this example, the lid-driven cavity flow is considered to illustrate the streamlines and pressure lines through P1b − P1 − P1 − P1 finite elements. The computational domain is considered similar as [69, 89]. The Stokes and microfracture-matrix fluid flow subdomains are assumed as Ωc = (0,1) × (1,1.25) and Ωp = (0,1) × (0,1), respectively with the interface Γ = (0,1) ×{1}. On the interface Γ between conduit and porous medium, four interface conditions (2.8)–(2.11) are utilized.
A modified driven cavity flow with the Dirichlet boundary conditions for the flow region is used,
In the dual-porosity region, homogeneous Dirichlet boundary conditions are imposed on the left, right and bottom wall for the microfracture and matrix pressure φf = 0 and φm = 0, respectively.
The value of the parameters ν, α, ρ, and μ are simply taken as 1.0. The intrinsic permeability kf and km are considered as 1.0. The body force \( \vec {f}\) and qp are assumed as 0. The mesh size is taken as h = 1/256.
In Figs. 8 and 9, the streamlines, flow speed, and contour lines are illustrated for the comparison purpose with the proposed TGM by considering all the parameters 1.0 which are similar to [89]. On the other hand, we show the lid-driven cavity flow for the smaller intrinsic permeability by choosing microfracture permeability kf = 0.01 and matrix permeability km = 10− 8 in Figs. 10 and 11 where streamlines and contour demonstrate similar flow behavior. As expected, the flow speed decreases due to the smaller value of the microfracture and matrix permeability.
Figure 12 illustrates the gradually decreasing the matrix intrinsic permeability from km = 10− 6 to 10− 10. As expected, the decrease of matrix intrinsic permeability produce slower flow speed which can be seen in the legend bar.
5 Conclusion and future work
In this contribution, a two-grid finite element discretization for the dual-permeability-Stokes fluid flow model is presented. In the first step, the approximate solution on the coarse grid is generated, while the results of the coarse grid are used to derive the solution on the fine grid in the second step. On the fine mesh, the global problem is decoupled into three parallel subproblems. The weak formulation is presented, and the optimal error estimate is derived for the proposed two-grid method. Numerical tests illustrate that the proposed method is stable and efficient. In the future, this method can be extended for the lowest-equal-order finite element method P1 − P1 − P1 − P1. The lowest-equal-order finite elements do not satisfy the benchmark inf-sup condition, which produces oscillation need to be restored by considering the stabilization term [69, 89]. On the other hand, two-grid method can be applied to study the time-dependent coupled problems where the main difficulty arises with the relationship between the time step size and the mesh refinement [91,92,93,94]. Furthermore, two-grid method will be applied for the nonlinear cases to investigate the dual-permeability-Navier-Stokes model [68, 75, 76]. The nonlinearity can cause enormous difficulty in handling the interface conditions as well as the error bounds. Besides, the current two-grid method can be improved by decoupling the coupled algorithm into several parallel subproblems to generate the coarse grid solution, which can significantly reduce the computational cost.
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All authors are partially supported by NSF of China (Grant No. 11971174), NSF of Shanghai (Grant No. 19ZR1414300), and Science and Technology Commission of Shanghai Municipality (Grant No. 18dz2271000).
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Nasu, N.J., Mahbub, M.A.A., Hussain, S. et al. Two-grid finite element method for the dual-permeability-Stokes fluid flow model. Numer Algor 88, 1703–1731 (2021). https://doi.org/10.1007/s11075-021-01091-z
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DOI: https://doi.org/10.1007/s11075-021-01091-z