Effective integration of reservoir rock-typing and simulation using near-wellbore upscaling

Chandra, Viswa Santhi shanti; Barnett, Andrew; Corbett, Patrick William Michael; Geiger, Sebastian; Wright, Paul; Steele, Richard; Milroy, Paul

doi:10.1016/j.marpetgeo.2015.05.005

Cited by 47 publications

(20 citation statements)

References 9 publications

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“…(3) Substituting (11) into (8) and projecting the whole equation onto the Hilbert space spanned by the POD modes ( = 1 ∼ ), one can finally obtain a linear equation system of in the scale of × , where is the number of POD modes in (11). Once the temporal coefficients are solved, the original variable can be directly reconstructed in (11), instead of the computation of (8).…”

Section: Basic Idea Of Proper Orthogonal Decompositionmentioning

confidence: 99%

“…This kind of longtime computation is usually not endurable in engineering. Petroleum engineers attempted several approaches to speed up oil reservoir simulations, including the scale-up approach [11][12][13][14][15] and parallel computation [16]. Proper orthogonal decomposition (POD) can reduce computational loads efficiently via a reduced-order model.…”

Section: Introductionmentioning

confidence: 99%

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Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition

Wang

2018

Geofluids

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High-precision and high-speed reservoir simulation is important in engineering. Proper orthogonal decomposition (POD) is introduced to accelerate the reservoir simulation of gas flow in single-continuum porous media via establishing a reduced-order model by POD combined with Galerkin projection. Determination of the optimal mode number in the reduced-order model is discussed to ensure high-precision reconstruction with large acceleration. The typical POD model can achieve high precision for both ideal gas and real gas using only 10 POD modes. However, acceleration of computation can only be achieved for ideal gas. The obstacle of POD acceleration for real gas is that the computational time is mainly occupied by the equation of state (EOS). An approximation method is proposed to largely promote the computational speed of the POD model for real gas flow without decreasing the precision. The improved POD model shows much higher acceleration of computation with high precision for different reservoirs and different pressures. It is confirmed that the acceleration of the real gas reservoir simulation should use the approximation method instead of the computation of EOS.

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Section: Basic Idea Of Proper Orthogonal Decompositionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition

Wang

2018

Geofluids

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“…Rock typing is a technical procedure in hydrocarbon reservoir characterization and classifying rocks based on their petrophysical properties for reservoir modelling purposes [1]. Determined rock types contain similar porosity, permeability, capillary pressure and dynamic behavior [1].…”

Section: Introductionmentioning

confidence: 99%

“…Determined rock types contain similar porosity, permeability, capillary pressure and dynamic behavior [1]. Rock typing is usually conducted primarily on core plugs and thin sections prepared from the cores.…”

Section: Introductionmentioning

confidence: 99%

“…However, ignoring the geological controls such as pore space evolution is caused by the focus on grouping samples with consistent petrophysical properties, rather than geological characteristics. It is also problematic to achieve a fit-for-purpose rock-typing scheme separate from the influence of diagenetic processes on characteristics such as rock petrophysic, hydrocarbon recovery efficiency and fluid in-place volumes [1] [2] [3] [4] and [5]. Integrating large scale dynamic data to the wireline scale (small scale) is another inevitable challenge.…”

Section: Introductionmentioning

confidence: 99%

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Inspecting the Reservoir Characteristics of the Burgan Formation of Soroosh Oil Field Applying Rock Typing Methods in the Context of Geological Studies

Ebrahimi¹,

Amini²,

Hajikazemi³

et al. 2017

OJG

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The Albian age Burgan Formation is one of the most important siliciclastic reservoirs in the Arabian Plate. Northwest of Persian Gulf is the main area in Iran invaded by these siliciclastic sediments. This study uses a new and comprehensive procedure to identify the reservoir characteristics of the Burgan Formation in Soroush oil field (NW Persian Gulf). Results from core and petrographic studies led identification of 7 microfacies (MF1 to MF7) that are grouped into 3 main facies association (FA1, to FA3). Results from reservoir characterization indicate a dramatic decrease in reservoir quality from bottom to top (FA1 toward FA3). Using the Flow Zone Indicator (FZI) method, 5 Hydraluic flow units (HFUs) were recognized in the formation. The HFUs are in a notable accordance with facies associations. The HFUs 1 and 2 correlate with theFA1, the HFUs 3 and 4 with the FA2 and the HFU5 cover intervals defined by FA3. Cluster analysis of wireline logs resulted in determination of 5 electrofacies (EF1 to EF5) which are in agreement with the ascertained HFUs. Inspecting the vertical distribution of FAs, HFUs and EFs, three distinct zones are determined. The lower zone is characterized by good reservoir quality, abundance of FA1, HFUs1 and 2 and also EFs 1 and 2 is observed there. The middle zone with a moderate reservoir quality and upper zone presents the poorest quality. In the middle zone FA2, HFUs3 and 4 and also EFs 3 and 4 are more abundant while in the upper one interval are clearly correlated with FA3, HFU5 and also EF5.

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Hierarchies of stratigraphic discontinuity surfaces in siliciclastic, carbonate and mixed siliciclastic‐bioclastic tidalites: Implications for fluid migration in reservoir quality assessment

Chiarella,

Longhitano,

Spalluto

et al. 2024

The Depositional Record

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The hierarchies of the stratigraphic discontinuity surfaces observed in ancient tidalites are qualitatively assessed, aiming to evaluate their role as possible preferential conduits for fluid migration. Three outcrop examples are presented from microtidal settings of southern Italy: (i) siliciclastic tidalites consisting of quartz‐rich cross‐stratified sandstones generated by strong two‐directional tidal currents flowing along a tidal strait; (ii) carbonate tidalites, which accumulated in a Cretaceous lagoon and tidal flat where peritidal cycles formed vertically‐stacked sequences of biopeloidal and fenestral packstones, wackestones and bindstones during repeated phases of Milankovitch‐scale sea‐level changes; (iii) mixed, siliciclastic‐bioclastic tidalites, deposited in a bay and recording offshore‐transition, to shoreface wave‐dominated and tide‐influenced environments. Observations made during this study suggest that fluid movement can be controlled by the presence of main bounding surfaces that occur at different dimensions, from large (hectometre)‐scale, to medium (decametre)‐scale, to smaller (metre)‐scales. These surfaces produced either by depositional or erosional processes, are characterised by different features and geometries in siliciclastic, carbonate and mixed siliciclastic‐bioclastic tidalites arguably revealing complex internal pathways for fluid flows. These results suggest that fluids propagating along the main discontinuities follow a dominant sub‐horizontal direction of propagation, associated with minor sub‐vertical movements, due to local internal surface geometries and interconnections and a general lack of fractures. This surface‐based approach to the study of fluid‐flow transmission within stratified rocks represents a conceptual attempt to predict fluid mobility and reservoir potential in tidalite‐bearing siliciclastic, carbonate and mixed reservoir rocks.

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Effective integration of reservoir rock-typing and simulation using near-wellbore upscaling

Cited by 47 publications

References 9 publications

Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition

Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition

Inspecting the Reservoir Characteristics of the Burgan Formation of Soroosh Oil Field Applying Rock Typing Methods in the Context of Geological Studies

Hierarchies of stratigraphic discontinuity surfaces in siliciclastic, carbonate and mixed siliciclastic‐bioclastic tidalites: Implications for fluid migration in reservoir quality assessment

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