New Analytical Correction for Multi-Phase Flow Effect in Near-Well Regions of Coarse-Grid System

Nakashima, Toshinori; Nomura, Masahiko

doi:10.2118/87067-ms

Cited by 4 publications

(3 citation statements)

References 8 publications

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“…Our semianalytical model thus offers a diagnosis of the numerics behind the nonmonotonic behavior while clearly isolating the mobility and heterogeneity effects (which are captured by m(S c w ) and the optimized k rj * respectively). Independently, Nakashima and Nomura (2004) also proposed a related analytical computation of the total mobility function for the well. This function was then applied with the k rj * for the injection wellblock, which were separately obtained under the assumptions of a linear flow field and capillary limit conditions.…”

Section: Near-well Two-phase Upscaling (Nw2p)mentioning

confidence: 99%

Accurate coarse modeling of well-driven, high-mobility-ratio displacements in heterogeneous reservoirs

Hui

Durlofsky

2005

Journal of Petroleum Science and Engineering

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Section: Near-well Two-phase Upscaling (Nw2p)mentioning

confidence: 99%

Accurate coarse modeling of well-driven, high-mobility-ratio displacements in heterogeneous reservoirs

Hui

Durlofsky

2005

Journal of Petroleum Science and Engineering

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“…There are several studies in the literature which discuss the issue of permeability upscaling in two phase flow regime [15][16][17][18][19][20][21][22][23][24] . Azoug et al, 15 , Cao et al, 23 and Barker et al, 24 have provided excellent reviews and evaluated the different pseudo-functions available in the literature and compared their validity in different flow regimes.…”

Section: Introductionmentioning

confidence: 99%

“…Lohne et al, 16 have presented a two stage upscaling method which accounts for the capillary heterogeneities at core scale. Nakashima et al, 17 have developed pseudo relative permeability curves for use in the well grid block as the saturation and pressure changes in this block are more drastic than in other cells. However most of these studies have mainly looked at oil-water relative permeability curves for use in waterflooding applications.…”

Section: Introductionmentioning

confidence: 99%

Predicting Primary Depletion Recovery of a Giant Light-Oil Carbonate Reservoir

Ayyalasomayajula

Kamath

Dehghani

et al. 2006

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractPredicting primary depletion recovery below the bubble point is a very difficult challenge, especially for carbonate reservoirs. Accurate predictions require sufficient laboratory data to cover the variability in response from the different rock types and laboratory procedures, and proper upscaling of laboratory data to simulation grid scales.Many recent studies have shown that laboratory-derived gas-oil relative permeability curves often depend on whether the tests were conducted using depletion drive or steady state methods. Though it may seem preferable to use laboratory data from depletion drive experiments for modeling solution gas drive recovery, these tests are complex and there is concern using data from tests conducted at pressure depletion rates much higher than that in the field. More significantly, such tests are expensive and it is not practical to conduct many depletion tests.We used mercury injection, porosity, permeability, CT scans, and thin section data to classify the giant carbonate reservoir into different rock types. Steady state gas-oil relative permeability tests on plug samples were then conducted to span these rock types, and P10-50-90 curves developed. We also carried out steady state and reservoir condition multi-rate depletion on select whole cores. This data was used to apply a correction to the steady state plug data, and this typically lowered the gas relative permeability curves.We next conducted numerous upscaling studies using sector models extracted from the full field simulation model. These studies showed that areal upscaling cause the core based critical gas saturation to be increased and the oil relative permeability to be decreased. Vertical upscaling, including the presence of high permeability streaks to represent fractured zones, has not yet shown much impact on the laboratory derived curves.Finally we developed a template to systematically modify the steady state relative permeability plug data to account for process and scale effects. The new P10-50-90 curves were then used in simulation predictions and results compared to that from the plug based curves.

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Accelerated History Matching Through Process Independent Scale-up Techniques in a Giant Carbonate Reservoir

Suzuki

Asada

Yoshida

et al. 2004

SPE Asia Pacific Conference on Integrated Modelling for Asset Management

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Although upscaling has been extensively investigated, a quantitative relationship between the multi-million block geological model and the upscaled flow model is likely to be lost during the history match process, primarily due to parameter modification on an upscaled model. In this paper, we propose a new history match procedure combined with an innovative faster upscaling technique. In the proposed procedure, after each history run, parameter modification for the next run was done on the detailed geological model in close collaboration with geologist. This loop was made possible with a new faster upscaling technique, distinct against the existing method, by adopting empirical correlations of computing upscaled absolute and relative permeabilities. A capillary-limit upscaling technique was applied for the case study, since a target reservoir is capillary dominant. In the case study, history match was conducted on a sector of an oil-wet carbonate reservoir under waterflooding for 20 years. In each modification, the revised geological model of three million blocks was upscaled to a flow model of 60 thousand blocks in a process independent manner with a scale-up factor of 50. The CPU speed-up factor was approximately 200: 10 days for the detailed model with massive parallel computing and an hour for the upscaled model with a personal computer. Even with such significant CPU time reduction, it was confirmed that the upscaled model still maintained the simulation quality of the detailed geological model. Introduction Recently, the size of a geological model has been becoming huge, e.g., multi-million-gridblock model, in order to describe the heterogeneity as much as possible. Direct transfer of such a huge geological model (detailed geological model) to a flow model would result in a too long CPU time in a flow simulation and be impossible even for nowadays computer capacity in terms of the required memory. In general, the objective of upscaling is to reduce the number of gridblocks of a flow model so that a flow simulation can be conducted in a reasonable range of a computation time. The requirement for upscaling is that the important characteristics of heterogeneity and multiphase flow are to be retained in the resultant upscaled flow model made up of the fewer number of gridblocks than the detailed geological model. In other words, upscaling is one of such techniques that assign representative properties to each simulation block of a coarse grid model given that a finely gridded model is available. In the literature, there are two major upscaling approaches: dynamic approaches and effective properties approaches (Ekrann and Dale 1992). Dynamic approaches adopt pseudo- functions based on the simulation results of an entire reservoir model or representative portion of a fine grid model. Thus, these approaches give accurate results limited to an imposed flow condition from which pseudofunctions are derived. However, the derivation is too time-consuming to upscale very large geological models. In addition, the pseudofunctions have many other deficiencies as criticized by Barker and Thiebeau (1997). On the other hand, effective properties approaches average flow properties from the information on sub-grid scale heterogeneity alone in which the local flow regime assumed to be extreme: viscous, gravity, or capillary dominated. These approaches, which work on the isolated coarse grid block, enable us to compute effective properties much faster than dynamic approaches and give accurate results if the appropriate assumption is made for the actual flow field.

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New Analytical Correction for Multi-Phase Flow Effect in Near-Well Regions of Coarse-Grid System

Cited by 4 publications

References 8 publications

Accurate coarse modeling of well-driven, high-mobility-ratio displacements in heterogeneous reservoirs

Accurate coarse modeling of well-driven, high-mobility-ratio displacements in heterogeneous reservoirs

Predicting Primary Depletion Recovery of a Giant Light-Oil Carbonate Reservoir

Accelerated History Matching Through Process Independent Scale-up Techniques in a Giant Carbonate Reservoir

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