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EAGE/AAPG 3rd Research Symposium - Developing and Managing Turbidite Reservoirs
- Conference date: 03 Oct 1998 - 09 Oct 1998
- Location: Almeria, Spain
- ISBN: 978-94-6282-120-0
- Published: 03 October 1998
1 - 20 of 43 results
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Deepwater Gulf of Mexico Development Overview
More LessThe economic viability of the Deepwater Gulf of Mexico Hydrocarbon Province has become widely accepted in the last couple of years. The efficient development of the deepwater petroleum resources requires a wide range of leading edge technologies. Proper integration and understanding of their interdependencies through each of the development stages are imperative to ensure successful application. The key role reservoir prediction has played on the development of the Gulf of Mexico fields is the focus in this paper.
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Turbidite Reservoir Architecture in the Gulf of Mexico - Insights from Field Development
More LessIn 1983, when Shell began to explore the deepwater Gulf of Mexico, not much information was available to indicate whether the turbidite accumulations being discovered would be able to produce sufficient hydrocarbon volumes at high enough rates to justify the capital investments required for field development. Reservoir architecture and connectivity were primary concerns. Numerous studies of turbidite outcrops, shallow subsurface analogs, and producing turbidite fields were undertaken to gain insights into turbidite depositional modeIs th at could be used to predict reservoir quality and production performance.
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Development Drilling Results from Selected Deepwater Gulf of Mexico Fields - Implications on Turbidite Reservoir Characterization and Production Performance Prediction
Authors G. Clemenceau, J. Colbert, F. Lockett and B. MussoComparison of reservoir characterization and performance estimates with development drilling results in the Deepwater GOM is challenging the accuracy of Amoco's pre-development predictions. Estimates of trap acreage, reservoir thickness, reservoir rock quaIity, and connectivity are compared below to new weIl results from severaI Viosca Knoll Miocene reservoirs currently under development.
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Early Drilling Results at Subsalt Mahogany Field - Exploitation Strategies for Thin-Bedded Turbidite Reservoirs, Gulf of Mexico
By W. K. CampMahogany field was discovered in 1993 and is the industry's first subsalt development project in the Gulf of Mexico. The success at Mahogany field proved the viability of a new play and helped to turn around declining exploration drilling trends in the Gulf of Mexico. The impact of the Mahogany discovery can be measured by the rejuvenated exploration activity in the outer continental shelf and upper slope.
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Production Characteristics of Sheet and Channelized Turbidite Reservoirs, Garden Banks 236 Field, Gulf of Mexico
Authors C. E. Stelting, W. J. Schweller, J. E. Florstedt, D. S. Fugitt, G. J. Herricks and M. R. WiseThe Garden Banks 236 Field is located in 700 feet (213 m) water depth in the northern Gulf of Mexico, and is situated about 150 miles (240 km) from Lafayette, Louisiana (U.S.A.). Dry gas is produced from middle Pleistocene (lllinoian) turbidites situated on two separate present-day geologic structures. This paper will address the production characteristics of the Block 191 structure which began producing in 1993 and has produced over 210 BCF cumulative gas to date from turbidite sheet (4500' Sand) and channel (8500' Sand) sand reservoirs. Understanding the distribution of shale breaks within both reservoir types is critical to managing the reservoirs because the shales compartmentalize gas production and control water encroachment through the gas reservoirs.
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Application of Deepwater Outcrop Analogues to 3D Reservoir Modelling - an Example from the Diana Field, Western Gulf of Mexico
Authors T. Garfield, M. Sullivan, L. Foreman, A. Liesch and D. JennetteArchitectural styles of sandbodies deposited in deepwater settings are highly variable and this variability in sandbody geometry and continuity affects both the exploration and production potential of deep-water sandstones. Outcrops span a critical gap in both scale and resolution between seismic data and well-bore data, and therefore can provide 2-D and sometimes 3-D views of variations in reservoir architectures.
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Petronius Project - Reservoir Characterization, Modelling, and Fluid-Flow Simulation
More LessOil and gas production from the Texaco-operated Petronius Compliant Tower will begin in early 1999. The field is located at Viosea Knoll Bloek 786 in 1750 feet of water. The Petronius Subsurface Development Team has employed fluid-flow simulation as the primary tooI for optimizing plans for development drilling and reservoir management.
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Characterization and Development of Turbidite Reservoirs in a Deepwater Channel-Levee and Lobe System, Ford Geraldine Unit, Permian Bell Canyon Formation, Delaware Basin, USA
Authors S. P. Dutton, M. D. Barton, M. A. Malik, G. B. Asquith, A. G. Cole, K. R. Pittaway and J. GogasReservoirs in deep-water sandstones of the Delaware Mountain Group in West Texas and New Mexico are characterized by low primary recovery efficiency (<14 percent). An integrated geological, geophysical, petrophysical, and engineering study of a representative Delaware Mountain Group field was performed to identify constraints on producibility.
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Geologic Building Blocks for Reservoir Characterization - Lessons Learned from the Permian Brushy Canyon Formation, West Texas
Authors M. H. Gardner, K. Johnson, M. Batzle, M. Sonnenfeld and B. SinexAccurately imaging the architecture of a hydrocarbon reservoir requires populating the three-dimensional space with the sediment bodies that compose it. But what scale geologic building block is best for constructing a reservoir architecture? Should one start with smaller facies, or use larger sediment bodies, representing architectural elements, or should one focus on even larger stratigraphic packages that are more easily resolved on subsurface analog data? Strategies used to characterize reservoir architecture are generally based on the scale of investigation. If the problem is small, then the focus is narrow.
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Reservoir Characterization of a Fan-Shaped Turbidite Complex in an Active-Margin Basin, Miocene Stevens Sandstone, Yowlumne Field, San Joaquin Basin, California
Authors M. S. Clark, R. K. Prather and J. D. MelvinYowlumne is a giant oil field, in the San Joaquin basin of Califomia, that has produced over 16.7 million m³ (105 million bbl) of oil from Upper Miocene, deep-water sandstones known as the "Stevens" (Figure 1). These sandstones, which represent clastic facies of organic-rich shales in the Monterey Formation (Figure 2), are some of the most prolific reservoirs in the basin and have contributed about 15% of over 1.9 billion m³ (12 billion bbl) of oil produced here since 1864. An integrated reservoir analysis enabled cost-effective exploitation of the distal margin of a layered, low-permeability, fan-shaped turbidite complex contained within the Yowlumne Stevens.
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Subsidence and Old Data Present Unique Challenges in Aging Turbidite Oil Fields - Examples of Successful Technological Solutions from the Wilmington Oil Field California USA
Authors D. D. Clarke and C. C. PhillipsThe Wilmington oil field of Los Angeles County California, the third largest in the United States, was discovered in 1932 and has been on continuous production ever since. Cumulative oil production has exceeded 2.5 billion barrels. Production is from Pliocene and Miocene Age basinal turbidite sands. There are seven productive zones that have generally been subdivided into 52 subzones. Locally the subzones have undergone detailed reservoir characterization in an attempt to better define the actual hydrologic units. The asymmetrical anticline is highly faulted and development proceeded from west to east through each of the ten fault blocks. In the areas with the longer production history (60years+) water cuts exceed 96% and the reservoirs are near the economic limit. Several new technologies have been applied to specific areas to improve the production efficiencies and thus prolong the field life.
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Reservoir Management in Selected Basin Floor Submarine Fan Reservoirs from the UKCS
Authors A. Leonard and M. BowmanThis paper reviews approaches to the exploitation of reserves from moderate to high net:gross submarine fan systems from the UK sector of the North sea. Examples are given from the Forties, Magnus and Andrew fields. It is shown how contrasting reservoir management approaches and experiences can be related to architectural elements of the different fan systems. The submarine fans range in age from Jurassic to Palaeocene and the development schemes from platform drilled 'conventional' wells to geosteered horizontal. These examples are broadly representative of other submarine fan reservoirs in the North Sea.
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Sleipner Øst Field, A Sand-Rich Palaeocene (Ty Formation) Gas-Condensate Reservoir Offshore Norway - Sedimentology, Stratigraphy, Heterogeneity and Paleocontact Influence on Reservoir Properties, Flow and Production
Authors S. K. Strømmen, C. Halvorsen, V. Langlais, G. V. Laursen, P. Nadeau and E. T. SamuelsenThe Sleipner Øst gas-condensate Field (and the minor neighbouring Loke Field) offshore Norway (Fig.1) started production 1 Oct. 1993. The Palaeocene Ty Formation is the main producing reservoir, a structural stratigraphic trap where the gas is reinjected until the year 2005 to keep up the pressure and produce the condensates. At present there are 12 production and 3 injection wells on the Field.
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Cretaceous Gravity Flow Deposits in the Northern North Sea - A Link Between Tectonic and Sequence Development
Authors M. Skibeli, T. Bugge and W. FjeldskaarThe Cretaceous succession in the northern North Sea is still an underexplored interval in the Norwegian North Sea. Although several wells have now penetrated sandstones of Cretaceous age, no big discoveries are yet made. Therefore there is a need of understanding these settings in more detail. The intervals have been very difficult to correlate due to complex tectonic and depositional setting.
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Depositional Elements and Processes and Within a Confined Palaeocene/Eocene Deepwater Depositional System - the Bittern Field, UK North Sea
By M. LeishmanThe aim of this presentation (and/or poster) is to describe the field evaluation, geological modelling and reservoir simulation of a Late Palaeocene/Eocene reservoir in the Central North Sea. The Bittern Field is a large four-way dip closure located within Block 29/1, close to the boundary of the Central Graben Mesozoic rift system. Thick sandstones within the Sele Formation, deposited by a variety ofmass-flow processes, occupy a narrow west-east oriented fairway, with sediment dervied from the west.
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Why Outcrop Characterization for Reservoir Studies?
By R. M. SlattDiscipline-integration within the petroleum industry during the past 10 years has changed the way in which geoscientists interact with reservoir engineers. Geoscientists have been forced from providing reservoir engineers with conceptual geological models to providing data-based, quantitative reservoir models which can address questions such as "how big is the container?", " how will this reservoir style perform?", "how widely must we space our expensive development wells in this geologic setting?", and "should we drill a vertical, slant, or horizontal well?
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Deepwater Sands Associated With Shelf-Slope-Basin Floor Clinoforms in the Eocene Central Basin of Spitzbergen
Authors R. Steel, D. Mellere and P. Plink-BjorklundOne km-high and 10 km-long mountainside exposures in the Eocene of the Central Basin of Spitsbergen allow a detailed examination and walk-out of 150-350m high, progradational to aggradational, clastic shelf-slope-basin floor clinoforms. This provides an unusual opportunity to analyze the nature and geometry of the linkage between shelf, slope and basin floor lithosomes, and particularly the possible controls on the occurrence of deep-water, basin-floor sandstone successions (20-100m thick). The latter occur only 6 times during the infill of the basin.
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Using Turbidite Outcrop Data to Influence Deepwater Development Decisions
By M. ChapinQualitative and quantitative data from outcrop analogues have provided valuable information for understanding and characterizing deepwater developments, spanning all aspects of subsurface characterization, from seismic net pay estimation to understanding producing gas-oil ratios in reservoir models.
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Subsurface Lessons from Tabernas Turbidites
By P. HaughtonYoung (Neogene), well-exposed and erosionally dissected turbidite successions like those of the Tabernas area, SE Spain, contain a wealth of information concerning the geometry and internal architecture of deep water successions.
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