IPARS

Integrated Parallel Accurate Reservoir Simulators (IPARS), developed under the directorship of Mary Wheeler at the Center for Subsurface Modeling, at the University of Texas’ Institute for Computational and Applied Mathematics, TICAM, is a framework for developing parallel models of subsurface flow and transport through porous media. It currently can simulate single phase (water only), two phase (water and oil) or three phase (water, oil and gas) flow through a multi-block 3D porous medium. IPARS can be applied to model water table decline due to overproduction near urban areas, or enhanced oil and gas recovery in industrial applications.


References in zbMATH (referenced in 29 articles , 1 standard article )

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  1. Brenner, Konstantin; Hennicker, Julian; Masson, Roland; Samier, Pierre: Hybrid-dimensional modelling of two-phase flow through fractured porous media with enhanced matrix fracture transmission conditions (2018)
  2. Wang, Kun; Liu, Hui; Luo, Jia; Chen, Zhangxin: Efficient CPR-type preconditioner and its adaptive strategies for large-scale parallel reservoir simulations (2018)
  3. Bui, Quan M.; Elman, Howard C.; Moulton, David J.: Algebraic multigrid preconditioners for multiphase flow in porous media (2017)
  4. Li, Zheng; Wu, Shuhong; Zhang, Chen-Song; Xu, Jinchao; Feng, Chunsheng; Hu, Xiaozhe: Numerical studies of a class of linear solvers for fine-scale petroleum reservoir simulation (2017)
  5. Qiao, Changhe; Wu, Shuhong; Xu, Jinchao; Zhang, Chen-Song: Analytical decoupling techniques for fully implicit reservoir simulation (2017)
  6. Xing, F.; Masson, R.; Lopez, S.: Parallel numerical modeling of hybrid-dimensional compositional non-isothermal Darcy flows in fractured porous media (2017)
  7. Yang, Haijian; Sun, Shuyu; Yang, Chao: Nonlinearly preconditioned semismooth Newton methods for variational inequality solution of two-phase flow in porous media (2017)
  8. Gratton, Serge; Hénon, Pascal; Jiránek, Pavel; Vasseur, Xavier: Reducing complexity of algebraic multigrid by aggregation. (2016)
  9. Brenner, K.; Groza, M.; Guichard, C.; Masson, R.: Vertex approximate gradient scheme for hybrid dimensional two-phase Darcy flows in fractured porous media (2015)
  10. Wang, Kun; Liu, Hui; Chen, Zhangxin: A scalable parallel black oil simulator on distributed memory parallel computers (2015)
  11. Chen, Jie; Sun, Shuyu; Wang, Xiao-Ping: A numerical method for a model of two-phase flow in a coupled free flow and porous media system (2014)
  12. Di Pietro, Daniele A.; Vohralík, Martin; Yousef, Soleiman: An a posteriori-based, fully adaptive algorithm with adaptive stopping criteria and mesh refinement for thermal multiphase compositional flows in porous media (2014)
  13. Ganis, Benjamin; Kumar, Kundan; Pencheva, Gergina; Wheeler, Mary F.; Yotov, Ivan: A global Jacobian method for mortar discretizations of a fully implicit two-phase flow model (2014)
  14. van Slingerland, P.; Vuik, C.: Fast linear solver for diffusion problems with applications to pressure computation in layered domains (2014)
  15. Hu, Xiaozhe; Xu, Jinchao; Zhang, Chensong: Application of auxiliary space preconditioning in field-scale reservoir simulation (2013)
  16. Kou, Jisheng; Sun, Shuyu: Convergence of discontinuous Galerkin methods for incompressible two-phase flow in heterogeneous media (2013)
  17. Müller, Eike; Guo, Xu; Scheichl, Robert; Shi, Sinan: Matrix-free GPU implementation of a preconditioned conjugate gradient solver for anisotropic elliptic PDEs (2013)
  18. Tavakoli, Reza; Pencheva, Gergina; Wheeler, Mary F.; Ganis, Benjamin: A parallel ensemble-based framework for reservoir history matching and uncertainty characterization (2013)
  19. Kou, Jisheng; Sun, Shuyu: A new treatment of capillarity to improve the stability of IMPES two-phase flow formulation (2010)
  20. Kou, Jisheng; Sun, Shuyu: On iterative IMPES formulation for two phase flow with capillarity in heterogeneous porous media (2010)

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