The Open Porous Media Flow reservoir simulator

Rasmussen, A.F.; Sandve, Tor Harald; Bao, Kai; Lauser, Andreas; Hove, Joakim; Skaflestad, Bård; Klöfkorn, Robert; Blatt, Markus; Rustad, Alf Birger; Sævareid, Ove; Lie, Knut–Andreas; Thune, Andreas

doi:10.1016/j.camwa.2020.05.014

Cited by 94 publications

(46 citation statements)

References 15 publications

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“…In the 3-dim experiments, due to boundary effects, slight heterogeneities within the porous pack, contact area CO2, and porous media, internal fingering merging does add substantial complication to the fingering phenomenon compared to 2-dim experiments [9,25,41]. The scaled experimental data forms a basis for the fine-tuning of the existing mathematical model and scaling-up [11,42]. As further work, we suggest carrying out more experiments in more different oil types (e.g., mixture of oil and different crude oil types with known compositions) using a wider range of permeabilities to gather more data.…”

Section: Resultsmentioning

confidence: 99%

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

et al. 2021

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During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure decay was faster in n-decane compared to crude oil for similar permeability (4 D), and the crude oil had a breakthrough time three times slower than in n-decane. The results were compared with similar experiments that have been carried out using water.

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Section: Resultsmentioning

confidence: 99%

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

et al. 2021

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“…CN is for "Constant-Neighbour", LN is for "Linear-Neighbour". The error quantities are defined by formulas (7)(8)(9). It is easy to see that the first and the second order terms are the same as in (A1), thus the local error is second order, which means that the CN method is first order.…”

Section: Discussionmentioning

confidence: 99%

“…Figure10Maximum errors defined by formula(7) as the function of the timestep-size in case of the Constant-neighbour methods.…”

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confidence: 99%

A class of new stable, explicit methods to solve the non‐stationary heat equation

Kovács

2020

Numerical Methods Partial

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We present a class of new explicit and stable numerical algorithms to solve the spatially discretized linear heat or diffusion equation. After discretizing the space and the time variables like conventional finite difference methods, we do not approximate the time derivatives by finite differences, but use constant-neighbor and linear-neighbor approximations to decouple the ordinary differential equations and solve them analytically. During this process, the time step size appears not in polynomial, but in exponential form with negative exponents, which guarantees stability. We compare the performance of the new methods with analytical and numerical solutions. According to our results, the methods are first and second order in time and can be much faster than the commonly used explicit or implicit methods, especially in the case of extremely large stiff systems.

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“…We employ the open-source reservoir simulator Flow [13] to conduct our experiments and test our alternative implementations and methods. Flow is provided by the Open Porous Media (OPM) initiative [14], which is a software collaboration in the domain of porous media fluid flow.…”

Section: Numerical Experimentsmentioning

confidence: 99%

On the impact of heterogeneity-aware mesh partitioning and non-contributing computation removal on parallel reservoir simulations

2021

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Parallel computations have become standard practice for simulating the complicated multi-phase flow in a petroleum reservoir. Increasingly sophisticated numerical techniques have been developed in this context. During the chase of algorithmic superiority, however, there is a risk of forgetting the ultimate goal, namely, to efficiently simulate real-world reservoirs on realistic parallel hardware platforms. In this paper, we quantitatively analyse the negative performance impact caused by non-contributing computations that are associated with the “ghost computational cells” per subdomain, which is an insufficiently studied subject in parallel reservoir simulation. We also show how these non-contributing computations can be avoided by reordering the computational cells of each subdomain, such that the ghost cells are grouped together. Moreover, we propose a new graph-edge weighting scheme that can improve the mesh partitioning quality, aiming at a balance between handling the heterogeneity of geological properties and restricting the communication overhead. To put the study in a realistic setting, we enhance the open-source Flow simulator from the OPM framework, and provide comparisons with industrial-standard simulators for real-world reservoir models.

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The Open Porous Media Flow reservoir simulator

Cited by 94 publications

References 15 publications

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

A class of new stable, explicit methods to solve the non‐stationary heat equation

On the impact of heterogeneity-aware mesh partitioning and non-contributing computation removal on parallel reservoir simulations

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