Petrophysical characterization of a heterolithic tidal reservoir interval using a process-based modelling tool

Nordahl, Kjetil; Ringrose, Philip; Wen, Renjun

doi:10.1144/1354-079303-613

Cited by 73 publications

(23 citation statements)

References 38 publications

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“…Rock heterogeneities at the sub-metre scale, such as laminae (mm) and bedding (cm), have a large impact on single and multiphase fluid flow properties, and are considered to be one of the largest controls on flow at larger scales (Corbett et al, 1992;Ringrose and Corbett, 1994;Nordahl et al, 2005;Li and Benson, 2015). Incorporating accurate heterogeneous flow properties into reservoir characterisation is therefore crucial to the successful modelling and prediction of fluid flow in the subsurface , which is important for applications such as groundwater hydrology, petroleum engineering and carbon sequestration (Ringrose and Bentley, 2015).…”

Section: Introductionmentioning

confidence: 99%

Characterising Drainage Multiphase Flow in Heterogeneous Sandstones

Jackson¹,

Agada²,

Reynolds³

et al. 2017

Preprint

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In this work, we analyse the characterisation of drainage multiphase flow properties on heterogeneous rock cores using a rich experimental dataset and mm-m scale numerical simulations. Along with routine multiphase flow properties, 3D sub-metre scale capillary pressure heterogeneity is characterised by combining experimental observations and numerical calibration, resulting in a 3D numerical model of the rock core. The uniqueness and predictive capability of the numerical models are demonstrated by accurately predicting the experimentally measured relative permeability of N 2 -DI water and CO 2 -brine systems in two distinct sandstone rock cores across multiple fractional flow regimes and total flow rates. The numerical models are used to derive equivalent relative permeabilities, which are upscaled functions incorporating the effects of sub-metre scale capillary pressure. The functions are obtained across capillary numbers which span four orders of magnitude, representative of the range of flow regimes that occur in subsurface CO 2 injection. Removal of experimental boundary artefacts allows the derivation of equivalent functions which are characteristic of the continuous subsurface. We also demonstrate how heterogeneities can be re-orientated and restructured efficiently to obtain large amounts of information about expected flow regimes through different small-scale rock structures. This analysis shows how combined experimental and numerical characterisation of rock samples can be used to derive equivalent flow properties from heterogeneous rocks.

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Section: Introductionmentioning

confidence: 99%

Characterising Drainage Multiphase Flow in Heterogeneous Sandstones

Jackson¹,

Agada²,

Reynolds³

et al. 2017

Preprint

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“…In the case of complex reservoirs, such as tidal heteroliths, this may involve cm-scale models (Jackson et al 2003;Nordahl et al 2005). In complex heterolithic reservoirs there may be several scales of modelling, with the results from a fine-scale set of models being used to condition the inputs for the next level of model (Elfenbein et al 2005;Ringrose et al 2005).…”

Section: Analogue Data In the Reservoir Modelling Workflowmentioning

confidence: 99%

The application of outcrop analogues in geological modelling: a review, present status and future outlook

2014

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Analogues, especially outcrop analogues, have played a central role in improving understanding of subsurface reservoir architectures. Analogues provide important information on geobody size, geometry and potential connectivity. The historical application of outcrop analogues for understanding geobody distributions in reservoirs is reviewed, from the pioneering work of the 1960s to the high-tech virtual outcrop methodologies of today. Four key types of analogue data are identified: hard data, which describe the dimensions and geometry of the geobody; soft data, which describe the conceptual relationships between different geobody types; training images, which record the dimensions, proportions and spatial relationship; and analogue production data, which are taken from direct subsurface production analogues. The use of these different data types at different stages of the geomodelling workflow is discussed and the potential sources of error considered. Finally, a review of geobody and analogue studies in different clastic environments is discussed with reference to selected previous work and the range of papers in the current volume.Over the last 30 years, computer-based, geocellular models have become a routinely used tool for understanding subsurface reservoirs (Budding & Inglin 1981; review in Keogh et al. 2007). Such models are typically built to aid field development and reservoir management business decisions, but also serve the purpose of integrating disparate scales and types of subsurface data, and visualizing complex three-dimensional (3D) distributions of rocks and fluids. Since the application of early modelling tools, to the present day, it has been common practice to supplement sparse subsurface datasets (e.g. wells and seismic) with data and concepts derived from reservoir analogues. The intention of this process is to generate more accurate representations of the subsurface than would otherwise be possible. Considerable effort has been expended in recent years by industry and academia on the description of reservoir analogues for this purpose. This paper examines the challenges inherent in selection and application of appropriate analogue data, particularly quantitative datasets, during construction of geological models.The most commonly used type of analogue is the outcrop, where information on geometric data that are limited in the subsurface is more readily available in cliff sections. Analogues may also include subsurface data but this is less common. This aspect is considered briefly in this review. The perspective on the application of analogues as discussed here is with regard to sedimentology and stratigraphy applied to hydrocarbon reservoir analysis, and the insights that 3D facies models bring to the distribution of petrophysical properties that control hydrocarbon flow. The discussion is based on clastic systems, but many of the aspects described are equally as applicable to carbonates, although they are not discussed explicitly here. Other branches of subsurface modelling, no...

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“…The SBED software is based on manipulating sine-functions, creating surfaces representing incremental sedimentation (Wen, 2004;Nordahl et al, 2005). Displacement of the surfaces creates a three-dimensional image mimicking bedform migration, and depositional environments as diverse as tidal channels and mass flows can be accurately recreated.…”

Section: Sbed Modelmentioning

confidence: 99%

“…The results presented in this paper come from the integration of sedimentary deposit modelling as well as seismic modelling (Wen, 2004;Nordahl et al, 2005;Stovas and Arntsen, 2006). The proposed methodology can be used for the modelling of seismic in order to test the realistic sedimentology and fluid saturation scenario.…”

Section: Introductionmentioning

confidence: 99%

Seismic Attributes from Ultra-Thin Layered Reservoir

Stovas

Landrø

Janbu

2007

Oil & Gas Science and Technology - Rev. IFP

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Résumé -Attributs sismiques d'un réservoir à couches ultra fines -Nous proposons d'utiliser la méthode d'attributs AVO sismiques (ordonnée à l'origine et pente) à partir d'un modèle géologique ultra fin basé sur le logiciel de modélisation SBED. Le logiciel SBED repose sur la manipulation de fonctions sinusoïdales qui créent des surfaces représentant une sédimentation progressive. Le déplacement des surfaces génère une image en trois dimensions réaliste en termes de sédimentologie et permettant de reconstituer avec précision des environnements de dépôt aussi divers que des chenaux de marée et des flux de masse. Au volume du dépôt modélisé, on peut associer des informations pétrophysiques, créant des propriétés intrinsèques telles que la porosité et la perméabilité (verticales et horizontales). La technique de calcul de la moyenne de Backus est utilisée pour la mise à l'échelle centimétrique (le rapport volumique sable-argile contrôle les propriétés acoustiques des couches ultra fines). Il en résulte des données pseudo-logs comprenant les paramètres anisotropiques intrinsèques. La modélisation sismique utilise la méthode de propagation de matrice et permet de prendre en compte tous les multiples en mode pur. Les attributs AVO qui en résultent seront dépendants de la fréquence. Dans le cadre de ce modèle ultra fin, nous pouvons tester différents scénarios de saturation de fluides et quantifier la probabilité d'éventuels analogues composites. Cette modélisation peut également être utilisée pour inverser des données sismiques réelles et retrouver le rapport sable-argile et la saturation des fluides pour les réservoirs ultra fins. Abstract -Seismic Attributes from Ultra-Thin Layered Reservoir -We propose the method of computation seismic AVO attributes (intercept and gradient) from ultra-thin geological model based on the SBED modelling software. The SBED software is based on manipulating sine-functions, creating surfaces representing incremental sedimentation. Displacement of the surfaces creates a three dimensional image mimicking bedform migration, and depositional environments as diverse as tidal channels and mass flows can be accurately recreated. The resulting modelled deposit volume may be populated with petrophysical information, creating intrinsic properties such as porosity and permeability (both vertical and horizontal). The Backus averaging technique is used for up-scaling within the centimetre scale (the intrinsic net-to-gross value controls the acoustic properties of the ultra-thin layers). It results in pseudo-

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Petrophysical characterization of a heterolithic tidal reservoir interval using a process-based modelling tool

Cited by 73 publications

References 38 publications

Characterising Drainage Multiphase Flow in Heterogeneous Sandstones

Characterising Drainage Multiphase Flow in Heterogeneous Sandstones

The application of outcrop analogues in geological modelling: a review, present status and future outlook

Seismic Attributes from Ultra-Thin Layered Reservoir

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