scholarly journals A Parallel Stochastic Framework for Reservoir Characterization and History Matching

2011 ◽  
Vol 2011 ◽  
pp. 1-19 ◽  
Author(s):  
Sunil G. Thomas ◽  
Hector M. Klie ◽  
Adolfo A. Rodriguez ◽  
Mary F. Wheeler
Keyword(s):  
Porous Media ◽  
Spatial Distribution ◽  
Multiphase Flow ◽  
History Matching ◽  
Reservoir Characterization ◽  
Well Log ◽  
Species Transport ◽  
Medium Permeability ◽  
Stochastic Framework ◽  
Sensor Information

The spatial distribution of parameters that characterize the subsurface is never known to any reasonable level of accuracy required to solve the governing PDEs of multiphase flow or species transport through porous media. This paper presents a numerically cheap, yet efficient, accurate and parallel framework to estimate reservoir parameters, for example, medium permeability, using sensor information from measurements of the solution variables such as phase pressures, phase concentrations, fluxes, and seismic and well log data. Numerical results are presented to demonstrate the method.

scholarly journals Emerging Advances in Petrophysics: Porous Media Characterization and Modeling of Multiphase Flow

Energies ◽  
2019 ◽  
Vol 12 (2) ◽  
pp. 282 ◽  
Author(s):  
Jianchao Cai ◽  
Shuyu Sun ◽  
Ali Habibi ◽  
Zhien Zhang
Keyword(s):  
Porous Media ◽  
Multiphase Flow ◽  
Oil And Gas ◽  
Reservoir Characterization ◽  
Experimental Studies ◽  
Flow Modeling ◽  
Special Issue ◽  
Fractal Approach ◽  
Unconventional Resources ◽  
Oil And Gas Resources

With the ongoing exploration and development of oil and gas resources all around the world, applications of petrophysical methods in natural porous media have attracted great attention. This special issue collects a series of recent studies focused on the application of different petrophysical methods in reservoir characterization, especially for unconventional resources. Wide-ranging topics covered in the introduction include experimental studies, numerical modeling (fractal approach), and multiphase flow modeling/simulations.

Enhanced-Velocity-Multiblock Method for Coupled Flow and Reactive-Species Transport Through Porous Media: Applications to Bioremediation and Carbon Sequestration

SPE Journal ◽  
2012 ◽  
Vol 17 (03) ◽  
pp. 794-804 ◽  
Author(s):  
S.G.. G. Thomas ◽  
M.F.. F. Wheeler
Keyword(s):  
Porous Media ◽  
Multiphase Flow ◽  
Co2 Sequestration ◽  
Mixed Finite Element ◽  
Computational Cost ◽  
Chemical Species ◽  
Reactive Species ◽  
Species Transport ◽  
Nonmatching Grids ◽  
Media Applications

Summary This paper presents a multiblock-discretization method—the enhanced-velocity mixed-finite-element method (EVMFEM) (Wheeler et al. 2002)—for coupled multiphase flow and reactive-species-transport modeling in porous-media applications. The method provides local mass balance and a continuous approximation of fluxes across interfaces of elements and subdomains. It can treat nonmatching grids, allowing for a flexible choice of grid refinements. Further, by distributing the blocks among processors such that each block has approximately the same number of elements, this method can be implemented efficiently in parallel, thereby offering further reductions in computational cost. The paper also presents recent application of EVMFEM to challenging problems such as compositional flow simulations of CO2 sequestration. Tests with EVMFEM suggest that it is advantageous to apply grid refinements around wells and to areas in which dynamics of chemical-species concentration is highest. Allowing for variable grid refinements greatly reduces the simulation cost, while preserving overall accuracy of the solution. For completeness, a few significant analytic results on convergence of the method are stated and referenced, omitting proof. This work is significant in advancing the discretization and application of EVMFEMs in reservoir-simulation development. Problems such as transport of chemical species in multiphase flow and CO2 sequestration have begun to assume significant importance in decisions regarding the preservation of our environment and in the safe and reliable means of delivering energy. This paper offers useful methods and some innovative future directions to address the huge computational costs involved in solving such complex problems.

Simultaneous History-Matching Approach by Use of Reservoir-Characterization and Reservoir-Simulation Studies

2016 ◽  
Vol 19 (04) ◽  
pp. 694-712 ◽  
Author(s):  
Guilherme Daniel Avansi ◽  
Célio Maschio ◽  
Denis José Schiozer
Keyword(s):  
Numerical Simulation ◽  
History Matching ◽  
Reservoir Characterization ◽  
Well Log ◽  
Log Data ◽  
Field Development ◽  
Geostatistical Methods ◽  
Well Production ◽  
Matching Process ◽  
Geological Models

Summary Reservoir characterization is the key to success in history matching and production forecasting. Thus, numerical simulation becomes a powerful tool to achieve a reliable model by quantifying the effect of uncertainties in field development and management planning, calibrating a model with history data, and forecasting field production. History matching is integrated into several areas, such as geology (geological characterization and petrophysical attributes), geophysics (4D-seismic data), statistical approaches (Bayesian theory and Markov field), and computer science (evolutionary algorithms). Although most integrated-history-matching studies use a unique objective function (OF), this is not enough. History matching by simultaneous calibrations of different OFs is necessary because all OFs must be within the acceptance range as well as maintain the consistency of generated geological models during reservoir characterization. The main goal of this work is to integrate history matching and reservoir characterization, applying a simultaneous calibration of different OFs in a history-matching procedure, and keeping the geological consistency in an adjustment approach to reliably forecast production. We also integrate virtual wells and geostatistical methods into the reservoir characterization to ensure realistic geomodels, avoiding the geological discontinuities, to match the reservoir numerical model. The proposed methodology comprises a geostatistical method to model the spatial reservoir-property distribution on the basis of the well-log data; numerical simulation; and adjusting conditional realizations (models) on the basis of geological modeling (variogram model, vertical-proportion curve, and regularized well-log data). In addition, reservoir uncertainties are included, simultaneously adjusting different OFs to evaluate the history-matching process and virtual wells to perturb geological continuities. This methodology effectively preserves the consistency of geological models during the history-matching process. We also simultaneously combine different OFs to calibrate and validate the models with well-production data. Reliable numerical and geological models are used in forecasting production under uncertainties to validate the integrated procedure.

JOINT IMPEDANCE INVERSION AND SPECTRAL DECOMPOSITION FOR DEEPWATER GAS RESERVOIR CHARACTERIZATION: A CASE STUDY IN SOUTH CHINA SEA

2020 ◽  
pp. 1-74
Author(s):  
Yaneng Luo ◽  
Mengqi Jiang ◽  
Kun Xiang ◽  
Yadi Yang ◽  
Handong Huang
Keyword(s):  
Spatial Distribution ◽  
Acoustic Impedance ◽  
Spectral Decomposition ◽  
Reservoir Characterization ◽  
Well Log ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Absorption Effect ◽  
Impedance Inversion ◽  
Gas Bearing

Gas reservoir characterization is one of the frontiers in seismic exploration. Acoustic impedance, one of the most effective seismic attributes, aims to describe the spatial distribution of rock properties. However, using acoustic impedance only is insufficient to describe gas-bearing layers accurately, in the case of rapid lithologic changes and complex geology in the deepwater area. The reflection seismograms show an absorption effect when seismic waves propagate through gas-bearing layers. The absorption effect can be used as an additional attribute to help gas reservoir characterization. Therefore, a new attribute is proposed for gas reservoir characterization in this study, which integrates the results of acoustic impedance and absorption coefficient. We estimate the acoustic impedance model by employing poststack impedance inversion and then we calculate probability distribution functions. Functions are classified into gas-bearing and non-gas layers. We discuss an absorption coefficient and obtain it from the spectrum gradient, where the gradient is calculated by spectral decomposition using the matching pursuit method. We apply the new attribute to characterize the spatial distribution and thickness of deepwater gas reservoirs in the Pearl River Mouth Basin. Well-log and geologic information show that the study area has an enrichment of gas reservoirs. Field data application shows the explicit distribution of the gas reservoir and in accordance with the well-log information, which indicates that the proposed attribute can improve gas reservoir characterization.

scholarly journals An open-source toolbox for multiphase flow in porous media

2015 ◽  
Vol 187 ◽  
pp. 217-226 ◽  
Author(s):  
P. Horgue ◽  
C. Soulaine ◽  
J. Franc ◽  
R. Guibert ◽  
G. Debenest
Keyword(s):  
Porous Media ◽  
Multiphase Flow ◽  
Open Source ◽  
Flow In Porous Media

A Robust Methodology To Simulate Water-Alternating-Gas Experiments at Different Scenarios Under Near-Miscible Conditions

SPE Journal ◽  
2017 ◽  
Vol 22 (05) ◽  
pp. 1506-1518 ◽  
Author(s):  
Pedram Mahzari ◽  
Mehran Sohrabi
Keyword(s):  
Porous Media ◽  
History Matching ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Two Phase ◽  
Matching Process ◽  
Water Alternating Gas ◽  
Three Phase ◽  
Three Phase Flow ◽  
Cycle Dependent

Summary Three-phase flow in porous media during water-alternating-gas (WAG) injections and the associated cycle-dependent hysteresis have been subject of studies experimentally and theoretically. In spite of attempts to develop models and simulation methods for WAG injections and three-phase flow, current lack of a solid approach to handle hysteresis effects in simulating WAG-injection scenarios has resulted in misinterpretations of simulation outcomes in laboratory and field scales. In this work, by use of our improved methodology, the first cycle of the WAG experiments (first waterflood and the subsequent gasflood) was history matched to estimate the two-phase krs (oil/water and gas/oil). For subsequent cycles, pertinent parameters of the WAG hysteresis model are included in the automatic-history-matching process to reproduce all WAG cycles together. The results indicate that history matching the whole WAG experiment would lead to a significantly improved simulation outcome, which highlights the importance of two elements in evaluating WAG experiments: inclusion of the full WAG experiments in history matching and use of a more-representative set of two-phase krs, which was originated from our new methodology to estimate two-phase krs from the first cycle of a WAG experiment. Because WAG-related parameters should be able to model any three-phase flow irrespective of WAG scenarios, in another exercise, the tuned parameters obtained from a WAG experiment (starting with water) were used in a similar coreflood test (WAG starting with gas) to assess predictive capability for simulating three-phase flow in porous media. After identifying shortcomings of existing models, an improved methodology was used to history match multiple coreflood experiments simultaneously to estimate parameters that can reasonably capture processes taking place in WAG at different scenarios—that is, starting with water or gas. The comprehensive simulation study performed here would shed some light on a consolidated methodology to estimate saturation functions that can simulate WAG injections at different scenarios.

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