**Peer Reviewed**

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**SPE Disciplines**

**Journal**

**Conference**

**Theme**

**Author**

- Chen, Hanming (2)
- Chen, Yangkang (2)
- Gan, Shuwei (1)
- Guo, Jia (1)
- Lee, Seong H. (1)
- Lee, Seong Hee (2)
- Li, Qingqing (2)
- Liu, Ying (1)
- Qin, Mo (1)
- Qu, Shan (3)
- Tchelepi, Hamdi A. (7)
- Wang, Xiaochen (1)
- Wang, Yufeng (1)
- Yuan, Jiang (1)
- Zhang, Hongjing (1)
- Zhang, Qi (1)
- Zhang, Qingchen (1)
**Zhou, Hui (12)**- Zu, Shaohuan (1)

**Concept Tag**

- accuracy (1)
- acquisition (2)
- adaptive reconstruction (1)
- Artificial Intelligence (3)
- auxiliary crg (1)
- basis function (5)
- Berenger (1)
- Berkhout (1)
- BILU (1)
- boundary condition (4)
- Chen (1)
- coarse block (4)
- coarse grid (3)
- coarse-scale operator (2)
- coarse-scale pressure (2)
- coefficient (1)
- compressibility (2)
- compressible flow (2)
- Computation (2)
- computational efficiency (1)
- construction (2)
- convergence (1)
- convolutional operator (1)
- correction function (1)
- correlated vibroseis data (1)
- CPML (1)
- CRG (1)
- crosscorrelation (1)
- Denote (2)
- dispersion (1)
- equation (9)
- FD coefficient (1)
- fine scale (1)
- fine-scale method (1)
- fine-scale pressure (2)
- fine-scale velocity (1)
- fine-scale velocity field (1)
- finite-difference method (1)
- force signal (1)
- formulation (4)
- Fourier Transform (1)
- fractional derivative (1)
- fractional laplacian operator (1)
- fractional laplacian viscoacoustic wave equation (1)
- fractional time derivative (1)
- frequency (1)
- frequency domain (1)
- fundamental signal (1)
- geophysics (2)
- grid (3)
- harmonic component (1)
- harmonic distortion (1)
- harmonic energy (1)
- harmonic noise reduction (1)
- Huang (1)
- incompressible flow (1)
- inverse Fourier transform (1)
- inversion (1)
- iteration (3)
- iteration matrix (1)
- iterative soft-thresholding algorithm (1)
- Jenny (3)
- june 2012 (1)
- Komatitsch (1)
- Lee (1)
- Marmousi model (1)
- Martin (1)
- mass conservation (2)
- matrix (3)
- Modeling & Simulation (5)
- multiphase flow (2)
- Multiscale Method (4)
- OBMM (2)
- Oil Recovery (1)
**operator (12)**- permeability (2)
- preconditioner (2)
- primal coarse block (2)
- prolongation operator (6)
- Reservoir Characterization (5)
- reservoir simulation (7)
- restriction operator (5)
- saturation (4)
- saturation equation (2)
- scaling method (7)
- SEG (1)
- seg denver 2014 (2)
- SGFD method (1)
- Simulation (1)
- TAM (2)
- Tchelepi (3)
- time step (2)
- Timestep (1)
- transport equation (3)
- Upstream Oil & Gas (12)
- Variational (1)
- velocity field (2)
- Vibroseis data (1)
- Wave Equation (2)
- Zhang (1)

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Wang, Yufeng (State Key Laboratory of Petroleum Resources and Prospecting, CNPC Key Lab of Geophysical Exploration, China University of Petroleum) | Zhou, Hui (State Key Laboratory of Petroleum Resources and Prospecting, CNPC Key Lab of Geophysical Exploration, China University of Petroleum) | Li, Qingqing (State Key Laboratory of Petroleum Resources and Prospecting, CNPC Key Lab of Geophysical Exploration, China University of Petroleum) | Chen, Hanming (State Key Laboratory of Petroleum Resources and Prospecting, CNPC Key Lab of Geophysical Exploration, China University of Petroleum) | Gan, Shuwei (State Key Laboratory of Petroleum Resources and Prospecting, CNPC Key Lab of Geophysical Exploration, China University of Petroleum) | Chen, Yangkang (The Unversity of Texas at Austin)

**Summary**

We apply the unsplit convolutional perfectly matched layer (CPML) absorbing boundary condition (ABC) to the viscoacoustic wave, which is derived from Kjartanssonโs constant-Q model, with second-order spatial derivatives and fractional time derivatives, to annihilate spurious reflections from near-grazing incidence waves in the time domain. Computationally expensive temporal convolution in the unsplit CPML formulation are resolved by an effective recursive convolution update strategy which calculates time integration with the trapezoidal approximation, while the fractional time derivatives are computed with the Grünwald- Letnikov (GL) approximations. We verify the results by comparison with the 2D analytical solution obtained from wave propagation in homogeneous Pierre Shale.

**Introduction**

Perfectly matched layer (PML) absorbing boundary condition was introduced by Bérenger (1994) for the numerical simulations of electromagnetic waves in an unbounded medium. It can theoretically absorb the incident waves at the interface with the elastic volume, regardless of their incidence angle or frequency. However, the performance degrades upon the finite-difference time domain (FDTD) discretization, especially in the case of grazing incidence (Roden and Gedney, 2000; Bérenger, 2002a, 2002b). To deal with this problem, Kuzuoglu and Mittra (1996) proposed a general complex frequency shifted (CFS) method, in which a Butterworth-type filter is implemented in the layer. This approach is also known as convolutional PML (CPML) or complex frequency shifted PML (CFS-PML) (Bérenger, 2002a, 2002b), which has been proved to be more effective in absorbing the propagating wave modes at grazing incidence than the classical PMLs (Roden and Gedney, 2000; Komatitsch and Martin, 2007; Martin and Komatitsch, 2009; Drossaert and Giannopoulos, 2007a, 2007b).

Generally, the unsplit CPML has been applied to the wave equation recast as a first-order system in velocity and stress (Komatitsch and Martin, 2007; Martin and Komatitsch, 2009; Chen et. al., 2014). However, it was rarely used in numerical schemes based on the wave equation written as a second-order system in displacement. This form of wave equation is commonly used in finite-element methods (FEM), the spectral-element method (SEM) and some finite-difference methods. Several unsplit CPMLs have already been applied to the second-order wave equations (Li and Matar, 2010; René Matzen, 2011). Li and Matar (2010) presented an unsplit CPML for the second-order wave equation that contains auxiliary memory variables to avoid the convolution operators. Matzen (2011) developed a novel CPML formulation based on the second-order wave equation with displacements as the only unknowns, which is implemented by slightly modifying the existing displacement-based finite element framework.

Berenger, convolutional operator, CPML, equation, formulation, fractional derivative, fractional time derivative, frequency, geophysics, Komatitsch, Martin, operator, Reservoir Characterization, second-order system, Simulation, unsplit CPML, Upstream Oil & Gas, visco-acoustic wave equation, Wave Equation

SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.72)

Chen, Hanming (China University of Petroleum, Beijing) | Zhou, Hui (China University of Petroleum, Beijing) | Zhang, Qingchen (China University of Petroleum, Beijing) | Zhang, Qi (China University of Petroleum, Beijing)

**Summary**

Two staggered-grid finite-difference (SGFD) methods with fourth- and sixth-order accuracy in time have been developed recently based on two new SGFD stencils. The SGFD coefficients are determined by Taylor-series expansion (TE), which is accurate only nearby zero wavenumber. We adopt the new two SGFD stencils and optimize the SGFD coefficients by minimizing the errors between the wavenumber responses of the SGFD operators and the first-order *k* (wavenumber)-space operator in a least-squares (LS) sense. We solve the LS problems by performing weighted pseudo-inverse of nonsquare matrices to obtain the SGFD coefficients, and to yield two LS based SGFD methods. Dispersion analysis and numerical examples demonstrate that our LS based SGFD methods can preserve the original fourth- and sixth-order temporal accuracy and achieve higher spatial accuracy than the existing TE based time-space domain SGFD methods.

**Introduction**

The staggered-grid finite-difference (SGFD) (Virieux, 1984) method has been widely used in seismic wave propagation modeling. Most of the SGFD applications adopt the traditional (2M, 2) scheme, which uses 2M-order Taylorseries expansion (TE) based FD operator to discretize spatial derivatives, and 2nd-order TE based FD operator to discretize temporal derivative. Although high-order spatial accuracy can be achieved by using a long stencil length, the temporal accuracy is only second-order. When a coarse time step is used, the traditional scheme suffers from obvious temporal dispersion during long time wave propagation.

Recently, Tan and Huang (2014a) propose two new SGFD methods with fourth-order and sixth-order accuracy in time respectively by incorporating a few of off-axial grid points into the standard SGFD stencil. The two methods are denoted as (2*M, * 4) and (2*M*, 6). The FD coefficients are determined in the time-space domain using TE approach. Althouth high-order temporal accuracy has been achieved, the TE based (2*M*, 4) and (*2M*, 6) methods still suffer from obvious spatial disperion when a large grid size or a short stencil length is adopted. Tan and Huang (2014b) continue to improve the spatial accuracy by using a nonlinear optimization to seek the optimal FD coefficients. However, the optimization requires repeated iterations, and the procedure may be time-consuming.

accuracy, coefficient, dispersion, FD coefficient, finite-difference method, Huang, lower subplot, operator, propagation, Reservoir Characterization, SGFD method, sgfd stencil, spatial accuracy, stencil, stencil length, subplot, time-space domain staggered-grid finite-difference method, upper subplot, Upstream Oil & Gas, wavenumber

SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)

Zu, Shaohuan (China University of Petroleum, Beijing) | Zhou, Hui (China University of Petroleum, Beijing) | Chen, Yangkang (The University of Texas at Austin) | Liu, Ying (China University of Petroleum, Beijing) | Qu, Shan (China University of Petroleum, Beijing)

**Summary**

Simultaneous-source technology has many advantages in improving the quality of illumination or decreasing survey period. Many researchers have achieved inspiring deblending results with the random dithering code. However, we find that the random dithering code cannot always get a good performance. This paper presents a periodically variational dithering code which can improve the sparsity of blending noise. The periodically variational dithering code is more effective for deblending and preserving the useful signal than the random dithering code. The deblending results of synthetic and field data demonstrate obviously that the proposed periodically variational dithering code can obtain a better performance than random dithering code.

**Introduction**

Traditional seismic acquisition survey is designed so that the time intervals between shots are sufficiently large in order to avoid the interference from other sources (Wapenaar et al., 2012). However, the large time interval results in low acquisition efficiency and increases the acquisition cost. One way to increase the acquisition efficiency is to make the spatial interval between shots sufficiently large. However, it results in poorly sampled seismic data. The acquisition designers are always suffering from the compromise between acquisition cost and data quality. Simultaneous-source acquisition is proposed to abandon the condition of non-overlapping shot records (Berkhout, 2008).

Simultaneous-source acquisition, which means firing more than one source with a small dithering delay, allows temporal overlap between shot records. Its potential benefits, which can improve the subsurface illumination with denser shot coverage and reduce survey time with wider shot coverage, have attracted many researchers (Moore et al., 2008; Berkhout, 2009; Mahdad et al., 2011; Abma et al., 2012; Beasley et al., 2012; Abma et al., 2012; Chen et al., 2014a). There are several types of approaches for separating the simultaneous-sources data. One type is based on inversion (Abma et al., 2012, Chen et al., 2014a), which uses iterative solver to solve the inversion problem. The other type is based on filtering (Huo et al., 2012; Chen et al., 2014b; Chen, 2014), which simply treats the deblending problem as a denoising problem. In both methods, the dithering code directly affects the quality of deblending. For example, it is natural that when the dithering time is large enough, deblending can obtain good results, however, at the same time, the survey period will increase. Thus, it is important to design a dithering code within smaller time range which can obtain a better separation.

acquisition, Artificial Intelligence, auxiliary crg, Berkhout, Chen, CRG, Denote, geophysics, inversion, iterative soft-thresholding algorithm, noise, operator, reference list, Reservoir Characterization, SEG, seismic data, separation, shot record, synthetic common-receiver gather, trace trace, Upstream Oil & Gas, useful signal, Variational

SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)

**Summary**

In this abstract, a new simple approach is presented to eliminate the harmonic noise in correlated vibroseis data. This technique is based on decomposition of the ground force signal into fundamental and harmonic components. Subsequently, we calculate the inverse-correlation operator and obtain the inverse-correlated data. Then, all the harmonics can be filtered out one by one after the inverse-correlated data cross-correlating with corresponding harmonic components. This method has some advantages as follows: First, it is simpler and more time-saving. Second, it can process truncated and incomplete correlated vibroseis seismic data. Moreover, this method only requires the ground force signal and shot location for each shot. Especially, the significant contribution of this procedure is a considerable reduction in the harmonics without any alteration of the desired signals. Both synthetic and field data are used to test its validity.

acquisition, correlated vibroseis data, crosscorrelation, force signal, Fourier Transform, frequency domain, fundamental signal, harmonic component, harmonic distortion, harmonic energy, harmonic noise reduction, operator, reduction, Reservoir Characterization, seg denver 2014, Upstream Oil & Gas, Vibroseis data

SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)

**Summary**

In this abstract, we propose a method to improve the computational efficiency of viscoacoustic wave equation with fractional Laplacian operator. For the sudden changes of velocity and Q, we have to compute the wave field with a block computing for every value of velocity and Q, otherwise strong noise is produced during computation. As a result the amount of calculation is huge for complex structure models. We use linear operators to replace fractional Laplacians operators to speed up the simulation. Numerical examples show that the new method is 25% faster than the conventional blocked method and the accuracy of our method is almost the same as the blocked method.

computational efficiency, equation, fractional laplacian operator, fractional laplacian viscoacoustic wave equation, inverse Fourier transform, kjartansson, Marmousi model, operator, Reservoir Characterization, seg denver 2014, snapshot, strong noise, time step, Upstream Oil & Gas, viscoacoustic wave equation, Wave Equation, Zhang

An efficient two-stage algebraic multiscale solver (TAMS) that converges to the fine-scale solution is described. The first (global) stage is a multiscale solution obtained algebraically for the given fine-scale problem. In the second stage, a local preconditioner, such as the Block ILU (BILU) or the Additive Schwarz (AS) method, is used. Spectral analysis shows that the multiscale solution step captures the low-frequency parts of the error spectrum quite well, while the local preconditioner represents the high-frequency components accurately. Combining the two stages in an iterative scheme results in efficient treatment of all the error components associated with the fine-scale problem. TAMS is shown to converge to the reference fine-scale solution. Moreover, the eigenvalues of the TAMS iteration matrix show significant clustering, which is favorable for Krylov-based methods. Accurate solution of the nonlinear saturation equations (i.e., transport problem) requires having locally conservative velocity fields. TAMS guarantees local mass conservation by concluding the iterations with a multiscale finite-volume step. We demonstrate the performance of TAMS using several test cases with strong permeability heterogeneity and large-grid aspect ratios. Different choices in the TAMS algorithm are investigated, including the Galerkin and finite-volume restriction operators, as well as the BILU and AS preconditioners for the second stage. TAMS for the elliptic flow problem is comparable to state-of-the-art algebraic multigrid methods, which are in wide use. Moreover, the computational time of TAMS grows nearly linearly with problem size.

BILU, boundary condition, coarse grid, equation, grid, iteration, iteration matrix, june 2012, mass conservation, matrix, Modeling & Simulation, msfvm, operator, permeability, permeability field, preconditioner, prolongation operator, reservoir simulation, restriction operator, scaling method, TAM, Tchelepi, Upstream Oil & Gas

Oilfield Places:

- Europe > Norway > North Sea > Tarbert Formation (0.99)
- Europe > Germany > North Sea > Tarbert Formation (0.99)

Recent advances in multiscale methods have shown great promise in modeling multiphase flow in highly detailed heterogeneous domains. Existing multiscale methods, however, solve for the flow field (pressure and total velocity) only. Once the fine-scale flow field is reconstructed, the saturation equations are solved on the fine scale. With the efficiency in dealing with the flow equations greatly improved by multiscale formulations, solving the saturation equations on the fine scale becomes the relatively more expensive part. In this paper, we describe an adaptive multiscale finite-volume (MSFV) formulation for nonlinear transport (saturation) equations. A general algebraic multiscale formulation consistent with the operator-based framework proposed by Zhou and Tchelepi (*SPE Journal*, June 2008, pages 267-273) is presented. Thus, the flow and transport equations are solved in a unified multiscale framework. Two types of multiscale operators--namely, restriction and prolongation--are used to construct the multiscale saturation solution. The restriction operator is defined as the sum of the fine-scale transport equations in a coarse gridblock. Three adaptive prolongation operators are defined according to the local saturation history at a particular coarse block. The three operators have different computational complexities, and they are used adaptively in the course of a simulation run. When properly used, they yield excellent computational efficiency while preserving accuracy. This adaptive multiscale formulation has been tested using several challenging problems with strong heterogeneity, large buoyancy effects, and changes in the well operating conditions (e.g., switching injectors and producers during simulation). The results demonstrate that adaptive multiscale transport calculations are in excellent agreement with fine-scale reference solutions, but at a much lower computational cost.

basis function, coarse block, Computation, construction, correction function, equation, formulation, iteration, march 2012, Modeling & Simulation, Multiscale Method, operator, prolongation operator, reservoir simulation, saturation, saturation equation, scaling method, Tchelepi, Timestep, total velocity, transport equation, Upstream Oil & Gas, velocity field

Previous research on multiscale methods for subsurface flow aims to obtain an efficient multiscale solution to the fine-scale problems. Such multiscale solution is usually a good approximation to the fine-scale problem. However, it has been reported that the multiscale solution deteriorates for high aspect ratios and channelized structures of permeability. Moreover, the multiscale solution does not converge to the fine-scale solution unless some special techniques are used.

In this paper, we propose an efficient two-stage algebraic multiscale (TAMS) method that converges to the fine-scale solution. The TAMS method consists of two stages, namely global and local stages. In the global stage, a multiscale solution is obtained purely algebraically from the fine-scale matrix. In the local stage, a local solution is constructed from a local preconditioner such as Block ILU(0) (BILU) or Additive Schwarz (AS) method. Spectral analysis shows that the multiscale solution step captures the low-frequency spectra in the original matrix very well and when combined with a local preconditioner that represents the high-frequency spectra, the full spectra can be well approximated. Thus the TAMS is guaranteed to converge to the fine-scale solution. Moreover, the spectra of the TAMS method tend to cluster together, which is a favorable property for Krylov subspace methods to converge fast. We also show that local mass conservation can be preserved if a multiscale solution step with the finite-volume restriction operator is applied before the iterative procedure exits. This allows for the TAMS method to be used to build efficient approximate solutions for multiphase flow problems that need to solve transport equations.

We test the numerical performance of the TAMS method using several challenging large-scale problems (fine-scale grid in the magnitude of one million) with complex heterogeneous structures and high aspect ratios. Different choices in the TAMS algorithm are employed, including the Galerkin or finite-volume type of restriction operator, BILU or AS preconditioner for the second stage, and the size of blocks for BILU and AS. The performance of TAMS is comparable or superior to the state-of-the-art algebraic multigrid (AMG) preconditioner when some optimal choice in the TAMS method is adopted. Moreover, the convergence of the TAMS method is insensitive to problem sizes, and the CPU time is almost linear to problem sizes. These indicate the TAMS method is efficient and

robust for large-scale problems.

boundary condition, coarse grid, convergence, equation, grid, iteration, local preconditioner, mass conservation, matrix, Modeling & Simulation, multiscale finite-volume method, operator, permeability, preconditioner, programming language, prolongation operator, reservoir simulation, restriction operator, scaling method, spe 141473, spectra, TAM, Upstream Oil & Gas

Oilfield Places:

- Europe > Norway > North Sea > Tarbert Formation (0.99)
- Europe > Germany > North Sea > Tarbert Formation (0.99)

Technology:

Recent advances in multiscale methods have shown great promise in modeling multiphase flow in highly detailed heterogeneous domains. Existing multiscale methods, however, solve for the flow field (pressure and total-velocity) only. Once the fine-scale flow field is reconstructed, the saturation equations are solved on the fine scale. With the efficiency in dealing with the flow equations greatly improved by multiscale formulations, solving the saturation equations on the fine scale becomes the relatively more expensive part. In this paper, we describe an adaptive multiscale finite-volume (MSFV) formulation for the nonlinear transport (saturation) equations. A general algebraic multiscale formulation consistent with the operator based framework proposed by Zhou and Tchelepi (SPEJ 13:267-173) is presented. Thus, the flow and transport equations are solved in a unified multiscale framework. Two types of multiscale operators, namely restriction and prolongation, are used to construct the multiscale saturation solution. The restriction operator is defined according to the local sum of the fine-scale transport equations in a coarse gridblock. Three adaptive prolongation operators are defined according to the local saturation history at a particular coarse block. The three operators have different computational complexity, and they are used adaptively in the course of a simulation run. When properly used, they yield excellent computational efficiency while preserving accuracy. This adaptive multiscale formulation has been tested using several challenging problems with strong heterogeneity, large buoyancy effects, and changes in the well operating conditions (e.g., switching injectors and producers during simulation). The results demonstrate that adaptive multiscale transport calculations are in excellent agreement with fine-scale reference solutions, but with a much lower computational cost.

basis function, coarse block, Computation, construction, equation, fine-scale velocity field, formulation, Jenny, Modeling & Simulation, Multiscale Method, operator, prolongation operator, reservoir simulation, restriction operator, saturation, saturation equation, scaling method, spe 119183, Tchelepi, time step, transport equation, Upstream Oil & Gas, velocity field

We propose an upscaling method that is based on dynamic simulation of a given model in which the accuracy of the upscaled model is continuously monitored via indirect error-measures. If the indirect measures are bigger than a specified tolerance, the upscaled model is dynamically updated with approximate fine scale information that is reconstructed by a multi-scale finite volume method (Jenny et al., JCP 217; 627-641, 2006). Upscaling of multi-phase flow entails a detailed flow information in the underlying fine scale. We apply adaptive prolongation and restriction operators for flow and transport equations in constructing an approximate fine scale solution. This new method eliminates inaccuracy associated with the traditional upscaling method which relies on prescribed inaccurate boundary conditions in computing upscaled variables. The new upscaling algorithm is validated for two-phase, incompressible flow in two dimensional porous media with heterogeneous permeabilities. It is demonstrated that the dynamically upscaled model achieves high numerical efficiency than the fine-scale models and also provides an excellent agreement with the reference solution computed from fine-scale simulation.

adaptive reconstruction, basis function, boundary condition, coarse grid, equation, fine scale, grid, Jenny, Lee, Modeling & Simulation, multiphase flow, Oil Recovery, operator, porous media, reconstruction, reference solution, reservoir simulation, saturation, scaling method, transmissibility, upscaled model, Upstream Oil & Gas

Thank you!