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Sensitivity of the impact of geological uncertainty on production from faulted and unfaulted shallow-marine oil reservoirs: objectives and methodsNormal access

Authors: T. Manzocchi, J.N. Carter, A. Skorstad, B. Fjellvoll, K.D. Stephen, J.A. Howell, J.D. Matthews, J.J. Walsh, M. Nepveu, C. Bos, J. Cole, P. Egberts, S. Flint, C. Hern, L. Holden, H. Hovland, H. Jackson, O. Kolbjørnsen, A. MacDonald, P.A.R. Nell, K. Onyeagoro, J. Strand, A.R. Syversveen, A. Tchistiakov, C. Yang, G. Yielding and R.W. Zimmerman
Journal name: Petroleum Geoscience
Issue: Vol 14, No 1, February 2008 pp. 3 - 15
DOI: 10.1144/1354-079307-790
Organisations: Geological Society of London
Language: English
Info: Article, PDF ( 3.72Mb )
Price: € 30

Summary:
Estimates of recovery from oil fields are often found to be significantly in error, and the multidisciplinary SAIGUP modelling project has focused on the problem by assessing the influence of geological factors on production in a large suite of synthetic shallow-marine reservoir models. Over 400 progradational shallow-marine reservoirs, ranging from comparatively simple, parallel, wave-dominated shorelines through to laterally heterogeneous, lobate, river-dominated systems with abundant low-angle clinoforms, were generated as a function of sedimentological input conditioned to natural data. These sedimentological models were combined with structural models sharing a common overall form but consisting of three different fault systems with variable fault density and fault permeability characteristics and a common unfaulted end-member. Different sets of relative permeability functions applied on a facies-by-facies basis were calculated as a function of different lamina-scale properties and upscaling algorithms to establish the uncertainty in production introduced through the upscaling process. Different fault-related upscaling assumptions were also included in some models. A waterflood production mechanism was simulated using up to five different sets of well locations, resulting in simulated production behaviour for over 35 000 full-field reservoir models. The model reservoirs are typical of many North Sea examples, with total production ranging from c. 15×106 m3 to 35×106 m3, and recovery factors of between 30% and 55%. A variety of analytical methods were applied. Formal statistical methods quantified the relative influences of individual input parameters and parameter combinations on production measures. Various measures of reservoir heterogeneity were tested for their ability to discriminate reservoir performance. This paper gives a summary of the modelling and analyses described in more detail in the remainder of this thematic set of papers.


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