Elasticity/saturation relationships using flow simulation from an outcrop analogue for 4D seismic modelling

Abstract

Three production scenarios have been simulated for three displacement mechanisms using three lithofacies models built at two scales (fine and coarse) from a 2D outcrop analogue. Analysis of the flow simulation results and the associated seismic modelling investigate the dependence of the time-lapse response on the lithofacies model and the vertical grid block size. Elastic attribute quantification from coarse-grid models requires a decision on the type of fluid saturation distribution (uniform or patchy) within the coarse-grid blocks. Here, empirical relations for scaling up the fluid bulk modulus are developed which, when inserted into standard Gassmann calculations, permit calibration of the response for the coarse-grid block model from the finer-scale model. At the coarse scale, fluid saturation changes during water injection and pressure depletion can be represented adequately by these relations but, for gas injection, it appears necessary to refer back to the fine-scale models. For the case of gas injection they cannot be generalized readily for each different lithofacies model and are thus observed to be outcrop dependent.

Petroleum Geoengineering

“…For gas injection, the Book Cliffs study found that fine-scale models would be required. From Kirstetter et al (2006). In that way, acoustic properties are not significantly different from relative permeability curves.…”

“…That final output might be used to capture variations in pore volume. From Kirstetter et al (2006). Used by permission.…”

“…To be effective, upscaling acoustic properties requires knowledge of architecture, properties, and simulations for each case. From Kirstetter et al (2006). They both depend on saturation and process and require upscaling for use in a typical simulation model.…”

Geophysical Properties of the Near Surface Earth: Seismic Properties

“…Such effects have been observed in nearly all rock types and an incomplete listing of contributions where such nonlinear effects have been observed includes those for igneous and metamorphic hard rocks (e.g., Birch, 1960Birch, , 1961Blake et al, 2013;Cheng and Toks€ oz, 1979;Cholach et al, 2005 Stanley, 2003;Goddard, 1990;Kern, 1982;Lyakhovsky et al, 1997;Todd and Simmons, 1972), sandstones (e.g., Christensen and Wang, 1985;Gomez et al, 2010;Jones and Nur, 1983;Khazanehdari and McCann, 2005;Khazanehdari and Sothcott, 2003;Lo et al, 1986;Prasad and Manghnani, 1997;Sayers, 2002;Sayers et al, 1990;Smith et al, 2010;Wyllie et al, 1958;Xu et al, 2006), carbonates (e.g., Alam et al, 2012;Azeemuddin et al, 2001;Fabricius et al, 2008;Melendez Martinez and Schmitt, 2013), and mudstones (Freund, 1992;Kwon et al, 2001;Sayers, 1999). Many workers have focused on different ways to describe this nonlinearity including the use of curve fitting (Carcione and Tinivella, 2001;Eberhart-Phillips et al, 1989;Freund, 1992;Khaksar et al, 1999;Kirstetter et al, 2006;Prasad and Manghnani, 1997;Prikryl et al, 2005;…”

A method for automatic history matching of a compositional reservoir simulator with multipoint flux approximation

“…Converting time-lapse seismic data to changes in pressures and saturations is a difficult task, which is currently not normally done. However, this is the topic of ongoing research; see, e.g., Landrøet al [17], Kirstetter et al [16], Buland and Ouair [5], and Ouair and Strønen [28].…”