PROJECT |
DESCRIPTION |
| Swan Hills Field, Alberta Canada |
Starting in mid-2002, a streamline full-field model and compositional and pseudo-miscible sector models are being engineered to quantify the expected performance of a CO2 miscible flood pilot in this multi-layered carbonate reservoir that has already been subjected to hydrocarbon miscible flooding. The dynamic models are both based upon a multi-million cell static (geocellular) reservoir model |
| Virginia Hills Field, Alberta Canada |
In 2001, a streamline model of this multi-layer carbonate waterflood was prepared to identify unswept oil volumes. The basis for the simulation was a 4 million-cell geostatistical model, upscaled to 100,000 simulation cells. The model was history-matched and several development options were analysed. |
| Chard Field , Alberta, Canada |
In 2001, 3-D compositional thermal models were used to evaluate the impact of gas zone depletion on underlying bitumen recovery by SAGD (steam-assisted gravity drainage). |
| Surmont Field, Alberta, Canada |
In 2001, a compositional model was used to simulate expected recovery of natural gas using flue gas as a displacing fluid |
| Kyle Field, North Sea |
In 2000, an extended well test in a fractured chalk reservoir was history-matched and forecasts were generated to provide the basis for final investment decision. |
| East Lost Hills Field, Southern California |
Several well tests in this HPHT fractured reservoir were history matched using a dual-porosity and the results were used to estimate reserves for the field. |
| S.W. Avalon Development Study, Hibernia Field |
The objective of this study was to develop a simulation model to predict waterflood performance in the multi-layered system under various configurations of geological setting, reservoir drainage area, geometry, wellbore location/orientation and wellbore completion. |
| Fractured Carbonate Gas Field, Northern Canada |
The objective of this 1998 study was to simulate the effect of various development strategies and offtake rates on the water-gas ratio and ultimate gas recovery from a complex faulted and fractured carbonate reservoir with an active water drive. The model results directed the client to specific recompletion procedures which were useful. |
| Fractured Carbonate Gas Condensate Field, Alberta |
Evaluation of this naturally fractured reservoir required the use of a dual porosity/permeability simulation model. The composition of the gas condensate fluid was characterised with eight pseudo-components using the Peng-Robinson Equation of State Model. Several field development options – including gas cycling and blowdown - were investigated. Under the gas cycling development scenario, the orientation of the fracture network was carefully study since it was crucial to recovery. The results were compared to a single porosity anisotropic model to assess gas breakthrough times and ultimate recovery predictions. |
| Medium/Heavy Oil Remboue Field, Gabon |
This 3D Tetrad black-oil simulation of a complex fluvial sandstone reservoir included the characterisation and importation of a geostatistical model of the reservoir. Various depletion scenarios were modelled to predict the production rate and recovery under primary compaction drive and waterflooding. This field was developed exclusively with horizontal wells and local grid refinement was used to properly describe their performance. |
| El Biban Fractured Light Oil Reservoir, Tunisia |
The objective of this 1998 study was to provide optimum operation parameters for a horizontal well drilled into this highly fractured and faulted carbonate reservoir. The pool has both an overlying gas cap and underlying aquifer. History matching of the model required alteration in the fracture description. Coning of fluids through the fracture networks was observed to have a significant impact on recovery. This model has been updated several times since. |
| Al Manzah Fractured Carbonate Oil Field, Tunisia |
The Al Manzah field is a complex reservoir system that is severely faulted, and highly fractured with an initial pressure near the bubble point resulting in a propensity toward free gas production. Characterization of the fracture network was achieved through FMI Logs and well test interpretation. A dual porosity/permeability reservoir simulation model was used to study the discovery well’s production performance. History matching of the model required a detailed understanding of flow mechanisms in the reservoir. The GOR response, flowing bottom hole pressure and reservoir pressure were matched to provide further development direction. |
