Enhanced Oil Recovery (EOR) Group

ECLIPSE blackoil modeling options

The ECLIPSE Blackoil reservoir simulator offers you EOR modeling options that allow comprehensive analysis. The EOR group enables you to model all modern EOR technologies.
 
Alkaline surfactant polymers (ASP) model: ASP flooding allows you to flexibly model multicomponent brine systems including multiple salts injection, ion exchange reactions between rock and surfactant, effective salinity, and ion transport.
 
Polymer Model: Five-component model (oil, water, gas, polymer, and brine) to study polymer-displacement processes. Allows you to control water mobility to model reduced viscous fingering and improve sweep efficiency; model polymer-inaccessible pore volume and salinity-dependent polymer properties; and manage the absorption of the polymer to the rock surfaces and the resulting reduction in aqueous phase-relative permeability. 

Surfactant model: Simulates enhanced waterfloods where the added surfactant reduces the capillary pressure between the water and oil phases. Also models salinity-dependent properties such as phase behavior and adsorption.

Solvent model: Four-component extension of the Todd and Longstaff empirical miscible flood model. A solvent phase can be introduced into the model to miscibly displace the reservoir hydrocarbons.

Foam model: Allows you to screen fields for possible foam injection projects. Enables you to control gas mobility and slow down the breakthrough of injected gas or gas production.
 
Multipartitioned tracers: Allows a tracer to be present in any number of phases. You can define pressure-dependent partitioning functions. For environmental partitioned tracers, adsorption, decay, and diffusion are generalized to all phases with phase-specific parameters. This option is particularly applicable for tracking H2S.
 
High pH (alkaline) model (simplified model currently available): Allows you to model in situ generation of surfactants leading to wettability changes and reduced oil-water interfacial tension.

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