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Lallier, Florent (Nancy Universite/INPL-INRA) | Viseur, Sophie (Laboratoire de Geologie des Systemes et Reservoirs Carbonates) | Borgomano, Jean (Laboratoire de Geologie des Systemes et Reservoirs Carbonates) | Caumon, Guillaume (ENS Geologie/INPL)
This reference is for an abstract only. A full paper was not submitted for this conference. 1) Introduction In the static and dynamic workflow of carbonate reservoirs, stratigraphic correlation of well data is one of the first and most influent steps. Indeed, facies distribution and petrophysical properties mainly control flow simulation and are often computed thanks to geostatistical methods, on grids based on stratigraphic correlation and structural data interpreted from seismic data (Borgomano ). In reservoir uncertainty modeling approaches, a unique grid is built, and uncertainties about layering geometry, facies distribution and petrophysical properties are handled using multiple geostatistical simulations (Charles et al, 2001). This article aims at assessing uncertainties due to stratigraphic correlations by also generating several set of possible stratigraphic well correlations. Several grids may then be built from these results and used for facies and property modeling. The method presented here generates automatically and stochastically sequence stratigraphic correlations of carbonate ramp systems by hierarchically integrating multiple pieces of 3D information as: interpreted well data, correlation lines extracted from seismic, and information obtained on analogs. 2) 3D Stochastic Stratigraphic Well Correlation method To perform the correlation, we propose a multi-dimensional and stochastic extension of the Dynamic Time Warping Algorithm (DTW, Myers et al., 1981) that we call msDTW. The DTW algorithm provides a way to find the optimal alignment between two time series [Myer et al., 1981]. This algorithm was used for the correlation of two wells by Smith and Waterman , Howell , Waterman and Raymond , Griffiths and Bake , Brown  for example. Lallier et al.  presented an improvement of the DTW, making the method stochastic and introducing a hierarchy to mimic the reasoning made by sedimentologists when correlating well data (Fig. 1), and applied this method to a carbonate ramp system.
Murillo-Muneton, G. (Instituto Mexicano del Petroleo) | Grajales-Nishimura, J.M. (Instituto Mexicano del Petroleo) | Cedillo-Pardo, E. (Instituto Mexicano del Petroleo) | Garcia-Hernandez, J. (PEMEX Exploracion y Produccion) | Hernandez-Garcia, S. (PEMEX Exploracion y Produccion)
Abstract Detailed stratigraphic and sedimentologic analysis of the main oil-producing stratigraphic interval at the Cantarell Oil Field suggests a general graded stratigraphic architecture for the Cretaceous-Tertiary (K/T) boundary carbonate sedimentary succession. Extensive well log data, core description and petrographic analysis, as well as comparison with contemporaneous outcrop analogs, indicate that this interval is dominated by a thick carbonate breccia genetically related to the Chicxulub meteorite-impact event occurred in northern Yucatan. The carbonate breccia deposit is consisting with a base-of-slope apron. Introduction Two distinct types of sedimentary accumulations have been documented near or at the Cretaceous-Tertiary (K/T) boundary stratigraphy across the Gulf of Mexico region. These sedimentary deposits are interpreted to be genetically related to the Chicxulub meteorite impact event occurred in northern Yucatan at Cretaceous/Tertiary boundary time. For example, in Alabama, Texas and northeastern Mexico, the K-T boundary terrigenous sedimentary succession consists of a high-energy coarse clastic unit, as much as 4 m thick, with ejecta material at its base and a clay bed with a typical Ir anomaly at its top. On the other hand, in K/T boundary outcrops of southeastern Mexico, in the Chiapas and Tabasco region, a deep-water carbonate breccia is overlain gradationally by a horizon with abundant ejecta material. Thickness of this carbonate breccia reaches several tens of meters. Because the extensive known evidences of the K/T boundary meteorite impact event in distant geologic outcrops, it is predictable that its effect may have been recorded in offshore locations at a closer proximity to the Chicxulub crater site, including the western margin of the Yucatan Platform. For example, a K/T boundary calcareous breccia similar to that in southeastern Mexico with a remarkable thickness of 450 m or more than 300 m has been reinterpreted as an impact-related sedimentary accumulation in western Cuba. Moreover, there is evidence for platform margin collapse and debris-flow deposits at several Ocean Drilling Program sites proximal to the Chicxulub crater induced by the Chicxulub impact event. The offshore zone in the western margin of the Yucatan platform, also known as the Campeche Bank or Campeche Bay, is the current most prolific oil-producing province in southeastern Mexico (Figure 1). The Cantarell oil field, the largest oil field in Mexico, is located in offshore Campeche and has produced more than 6,934 million barrels of oil and 2,954 billion of cubic feet of gas. It contains additional recoverable reserves of 10,176 million barrels of oil and 5,169 billion of cubic feet of gas. Oil production in the Cantarell oil field, and nearby fields, is obtained from four different stratigraphic horizons including the Upper Jurassic (Oxfordian and Kimmeridgian), Lower Cretaceous and a K/T boundary carbonate breccia (Figure 2). The main oil-producing K/T boundary carbonate breccia in the Cantarell oil field is part of a sedimentary succession that contains numerous stratigraphic, sedimentologic, and mineralogic characteristics that suggest a genetic link to the Chicxulub impact event in northern Yucatan. Although this important petroliferous stratigraphic unit underwent a subsequent complex history of diagenetic processes and tectonic deformation, it is critical to know its internal stratigraphic array for exploitation and exploration aims. In order to understand better the responsible mechanisms that gave place to the stratigraphic architecture of this unique naturally fractured carbonate reservoir, we examine in this paper a broad geologic data set.
Al Mershed, Mohammad (Kuwait Oil Company) | Al Wazzan, Hajar (Kuwait Oil Company) | Al-Sahlan, Ghaida (Kuwait Oil Company) | Al Ali, Salem (Kuwait Oil Company) | Hawie, Nicolas (Beicip-Franlab) | Richet, Remy (Beicip-Franlab)
This work comes in the context of a renewed interest in the exploration of deep Jurassic carbonate targets along the The Lower Jurassic Marrat Formation is known to be a main Arabian Plate and more specifically in Kuwait. Previous reservoir target along Kuwait, it informally classified into regional and local studies conducted on the Lower Jurassic Lower, Middle and Upper units/members where the middle Marrat Formation focused mainly on structural traps, one is considered as the main reservoir unit. Through this however a need to tackle complex carbonate systems is onshore/offshore regional-scale study, a high-resolution required at a stratigraphic level in order to better identify and stratigraphic framework is developed for the first time based map subtle trapping mechanisms onshore and offshore.
Abstract This paper concerns a super-giant carbonate oil field in Abu Dhabi, UAE (first oil production in 1962). Remaining reserves are mostly located in Lower Cretaceous carbonate build-up and prograding basin-margin deposits of the Shuaiba Formation. The principal challenges to maintain future production are pressure decline and uneven water advance. A key to understanding dynamic flow behavior is the spatial distribution of flow barriers, facies, diagenesis and faulting / fracturing in the prograding clinoform domain. The static model needs to accurately capture these heterogeneities by combining interpolation of reservoir parameters from wells with structural and sedimentological trends extracted from 3D seismic data. A comprehensive work program was initiated to understand the depositional evolution of the reservoirs using a sequence stratigraphic approach. The application of high-resolution sequence stratigraphy (recognition of 3rd and 4th order sequences) associated with detailed seismic interpretation of the clinoform domain represents a new approach rarely successful in carbonate reservoirs. Low permeability carbonate mudstone facies associated with transgression in the clinoform domain create local vertical barriers to fluid flow. The progradational clinoform topsets contain the best reservoir facies with a thickness distribution systematically related to position within the clinoform. Sequences of 3rd and 4th order have been interpreted to generate a seismically constrained stratigraphic framework. High quality 3D seismic combined with a thorough description of stratigraphic architecture provides a new approach to populating the reservoir model with reservoir facies (former lithostratigraphic units) honoring the depositional shapes from seismic interpretation. Combining the stratigraphic surfaces of the clinoforms with the lithological surfaces as property boundaries derived from the progradational geometries represents a new approach to reservoir modeling. The current pressure maintenance scheme is through peripheral water injection, with some pattern injection in the lower parts of the clinoforms. The preferred flow paths of injected fluids are strongly controlled by the geometry of clinoforms, and an understanding of this enables more accurate prediction of the pressure fronts and future water / gas breakthrough. Development optimization plans currently being evaluated will incorporate the reservoir property trends derived from the spatial distribution of stratigraphic sequences (3rd and 4th order). The location of proposed simulation and production pilot patterns has been based a facies interpolation methodology within a sequence stratigraphic framework. INTRODUCTION For accurate reservoir modeling, reconciling a lithostratigraphic (facies-based) layering with a sequence stratigraphic framework is a challenging task. In this field located onshore Abu Dhabi and developed by the Abu Dhabi Company for Onshore Oil Operations (ADCO), an up-to-date model was required to cope with production decisions that are critical for future reserve enhancement, addressing two main issues concerning fluid flow in the reservoir:Uneven water advance due to peripheral water injection Pressure drop in the north of the field and the appropriate design of injectors/producers to cope with reservoir heterogeneity trends.
The Leonardian succession in the Eastern Shelf of Permian Basin typically displays a wide range of geologic and petrophysical properties that make the efficient recovery of hydrocarbons difficult, once known as the largest uneconomical field in the Permian Basin. Despite decades of exploitation, recovery from the Leonardian rarely exceeds 8-12%. Lack of scientific attention hampered any application of new methods for reservoir analysis. In this study, high-frequency sequence architecture and 3-D seismic attribute analysis combined with wireline-log data have been launched to correct this situation and to characterize the reservoirs. This effort has involved four sequence stratigraphic units and various sedimentary facies types are identified on siliciclastic-carbonate dominated shelf margin. These new studies provide an important basis for future evaluations of Leonardian potential.
Presentation Date: Tuesday, September 26, 2017
Start Time: 2:15 PM
Presentation Type: ORAL