Simulating the Outcrop: Surface To Subsurface Integration of a Carbonate Reservoir, Khuff Formation, Oman

Reijnders, Gert-jan C.A.; Al-Mohannadi, Nasser Saqer; Pöppelreiter, Michael; Finlay, Sharon; Bodewitz, Gerard; Oreibi, Lama Al; Zampetti, Valentina; Al-Kindy, Sulaiman; Amthor, Joachim E.; Koehrer, Bastian; Aigner, Thomas

doi:10.2118/118332-ms

Cited by 2 publications

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“…The influence of these baffles on fluid flow and dynamic reservoir simulations was tested in different scenarios by Reijnders et al (2008) and Al-Oreibi et al (2009). Results of these studies were used to Table 3.…”

Section: Facies Modelling Results: Implications For Subsurface Modelsmentioning

confidence: 99%

Near Well‐scale Heterogeneities in a Khuff Outcrop Equivalent (Saiq Plateau, Al Jabal Al Akhdar, Sultanate of Oman)

Zeller

Koehrer

Adams

et al. 2011

Journal of Petroleum Geology

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The Middle Permian to Lower Triassic Khuff Formation is one of the world's most prolific hydrocarbon reservoirs. This study is part of a research project on Khuff outcrop equivalents whose overall aim is to investigate the reservoir architecture on different scales. The present paper focuses on heterogeneities in Khuff-equivalent grainstones at the near well scale.An outcrop in the Oman Mountains, where the Khuff-equivalent Saiq and Mahil Formations are exposed in an area 1800 m long by 100 m high, was studied to map lateral and vertical depositional heterogeneities. The investigated section represents parts of three third-order sequences: the upper part of Khuff sequence (KS)3 (grain-dominated), the whole of KS2 (muddominated), and the lower part of KS1 (grain-dominated). Real-Time Kinematic GPS, satellite imagery, outcrop gamma-ray and digitized sedimentary logs were used for outcrop description and were integrated into a three-dimensional digital outcrop model.The resulting 3D facies model indicates that the apparently simple, layer-cake geometry of the grainstone reservoir facies shows pinching and swelling with a standard deviation of 12.75% of bed thickness. These thickness variations may influence volume calculations during reservoir assessments. The heterogeneities of grainstone bodies are represented by compositional (ooid, peloid or intraclast-dominated) and grain-size variations.Muddy event beds at the cm-scale were mapped out in detail in a 200 x 40 m outcrop window and together form a dense network of potential baffles to fluid flow. The thickness of these beds varies significantly due to syndepositional erosion.An important conclusion of this near well-scale study is that the perceived simple, layer-cake Khuff-equivalent succession in the study area is in fact heterogeneous in mud-rich deposits, while grain-rich deposits extend over a wide area with some thickness variations. These findings can be directly applied in Khuff subsurface correlation and modelling attempts.

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Section: Facies Modelling Results: Implications For Subsurface Modelsmentioning

confidence: 99%

Near Well‐scale Heterogeneities in a Khuff Outcrop Equivalent (Saiq Plateau, Al Jabal Al Akhdar, Sultanate of Oman)

Zeller

Koehrer

Adams

et al. 2011

Journal of Petroleum Geology

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Numerical simulation of fluid-flow processes in a 3D high-resolution carbonate reservoir analogue

Agada

Chen

Geiger

et al. 2014

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A high-resolution three-dimensional (3D) outcrop model of a Jurassic carbonate ramp was used in order to perform a series of detailed and systematic flow simulations. The aim of this study was to test the impact of small- and large-scale geological features on reservoir performance and oil recovery. The digital outcrop model contains a wide range of sedimentological, diagenetic and structural features, including discontinuity surfaces, shoal bodies, mud mounds, oyster bioherms and fractures. Flow simulations are performed for numerical well testing and secondary oil recovery. Numerical well testing enables synthetic but systematic pressure responses to be generated for different geological features observed in the outcrops. This allows us to assess and rank the relative impact of specific geological features on reservoir performance. The outcome documents that, owing to the realistic representation of matrix heterogeneity, most diagenetic and structural features cannot be linked to a unique pressure signature. Instead, reservoir performance is controlled by subseismic faults and oyster bioherms acting as thief zones. Numerical simulations of secondary recovery processes reveal strong channelling of fluid flow into high-permeability layers as the primary control for oil recovery. However, appropriate reservoir-engineering solutions, such as optimizing well placement and injection fluid, can reduce channelling and increase oil recovery.

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Simulating the Outcrop: Surface To Subsurface Integration of a Carbonate Reservoir, Khuff Formation, Oman

Abstract: Careful gathering and analysis of outcrop analogue data is a valuable data source for enhancing the understanding of analogue hydrocarbon reservoirs. However, information from outcrops is commonly limited to static descriptions, i.e. reservoir body dimension and geometry.

Cited by 2 publications

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Near Well‐scale Heterogeneities in a Khuff Outcrop Equivalent (Saiq Plateau, Al Jabal Al Akhdar, Sultanate of Oman)

Near Well‐scale Heterogeneities in a Khuff Outcrop Equivalent (Saiq Plateau, Al Jabal Al Akhdar, Sultanate of Oman)

Numerical simulation of fluid-flow processes in a 3D high-resolution carbonate reservoir analogue

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